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FERC FINANCIAL REPORT
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These reports are mandatory under the Federal Power Act, Sections 3, 4(a), 304 and 309, and 18 CFR 141.1 and 141.400. Failure to report may result in criminal fines, civil penalties and other sanctions as provided by law. The Federal Energy Regulatory Commission does not consider these reports to be of confidential nature
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Exact Legal Name of Respondent (Company) |
Year/Period of Report End of: |
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Schedules |
Pages |
| Comparative Balance Sheet | 110-113 |
| Statement of Income | 114-117 |
| Statement of Retained Earnings | 118-119 |
| Statement of Cash Flows | 120-121 |
| Notes to Financial Statements | 122-123 |
| FERC FORM NO.
REPORT OF MAJOR ELECTRIC UTILITIES, LICENSEES AND OTHER |
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IDENTIFICATION |
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01 Exact Legal Name of Respondent
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02 Year/ Period of Report
End of: |
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03 Previous Name and Date of Change (If name changed during year)
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04 Address of Principal Office at End of Period (Street, City, State, Zip Code)
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05 Name of Contact Person
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06 Title of Contact Person
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07 Address of Contact Person (Street, City, State, Zip Code)
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08 Telephone of Contact Person, Including Area Code
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09 This Report is An Original / A Resubmission
(1)
☑ An Original ☐ A Resubmission |
10 Date of Report (Mo, Da, Yr)
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| Annual Corporate Officer Certification | ||||
| The undersigned officer certifies that: I have examined this report and to the best of my knowledge, information, and belief all statements of fact contained in this report are correct statements of the business affairs of the respondent and the financial statements, and other financial information contained in this report, conform in all material respects to the Uniform System of Accounts. | ||||
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03 Signature
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04 Date Signed (Mo, Da, Yr)
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| Title 18, U.S.C. 1001 makes it a crime for any person to knowingly and willingly to make to any Agency or Department of the United States any false, fictitious or fraudulent statements as to any matter within its jurisdiction. | ||||
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Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
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LIST OF SCHEDULES (Electric Utility) |
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Enter in column (c) the terms "none," "not applicable," or "NA," as appropriate, where no information or amounts have been reported for certain pages. Omit pages where the respondents are "none," "not applicable," or "NA". |
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| Line No. |
Title of Schedule (a) |
Reference Page No. (b) |
Remarks (c) |
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ScheduleIdentificationAbstract Identification |
1 | ||
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ScheduleListOfSchedulesAbstract List of Schedules |
2 | ||
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1 |
ScheduleGeneralInformationAbstract General Information |
101 | |
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2 |
ScheduleControlOverRespondentAbstract Control Over Respondent |
102 | |
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3 |
ScheduleCorporationsControlledByRespondentAbstract Corporations Controlled by Respondent |
103 | |
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4 |
ScheduleOfficersAbstract Officers |
104 | |
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5 |
ScheduleDirectorsAbstract Directors |
105 | |
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6 |
ScheduleInformationOnFormulaRatesAbstract Information on Formula Rates |
106 | |
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7 |
ScheduleImportantChangesDuringTheQuarterYearAbstract Important Changes During the Year |
108 | |
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8 |
ScheduleComparativeBalanceSheetAbstract Comparative Balance Sheet |
110 | |
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9 |
ScheduleStatementOfIncomeAbstract Statement of Income for the Year |
114 | |
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10 |
ScheduleRetainedEarningsAbstract Statement of Retained Earnings for the Year |
118 | |
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12 |
ScheduleStatementOfCashFlowsAbstract Statement of Cash Flows |
120 | |
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12 |
ScheduleNotesToFinancialStatementsAbstract Notes to Financial Statements |
122 | |
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13 |
ScheduleStatementOfAccumulatedOtherComprehensiveIncomeAndHedgingActivitiesAbstract Statement of Accum Other Comp Income, Comp Income, and Hedging Activities |
122a |
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14 |
ScheduleSummaryOfUtilityPlantAndAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract Summary of Utility Plant & Accumulated Provisions for Dep, Amort & Dep |
200 | |
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15 |
ScheduleNuclearFuelMaterialsAbstract Nuclear Fuel Materials |
202 |
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16 |
ScheduleElectricPlantInServiceAbstract Electric Plant in Service |
204 | |
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17 |
ScheduleElectricPropertyLeasedToOthersAbstract Electric Plant Leased to Others |
213 |
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18 |
ScheduleElectricPlantHeldForFutureUseAbstract Electric Plant Held for Future Use |
214 | |
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19 |
ScheduleConstructionWorkInProgressElectricAbstract Construction Work in Progress-Electric |
216 | |
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20 |
ScheduleAccumulatedProvisionForDepreciationOfElectricUtilityPlantAbstract Accumulated Provision for Depreciation of Electric Utility Plant |
219 | |
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21 |
ScheduleInvestmentsInSubsidiaryCompaniesAbstract Investment of Subsidiary Companies |
224 | |
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22 |
ScheduleMaterialsAndSuppliesAbstract Materials and Supplies |
227 | |
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23 |
ScheduleAllowanceInventoryAbstract Allowances |
228 | |
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24 |
ScheduleExtraordinaryPropertyLossesAbstract Extraordinary Property Losses |
230a |
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25 |
ScheduleUnrecoveredPlantAndRegulatoryStudyCostsAbstract Unrecovered Plant and Regulatory Study Costs |
230b |
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26 |
ScheduleTransmissionServiceAndGenerationInterconnectionStudyCostsAbstract Transmission Service and Generation Interconnection Study Costs |
231 |
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27 |
ScheduleOtherRegulatoryAssetsAbstract Other Regulatory Assets |
232 | |
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28 |
ScheduleMiscellaneousDeferredDebitsAbstract Miscellaneous Deferred Debits |
233 | |
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29 |
ScheduleAccumulatedDeferredIncomeTaxesAbstract Accumulated Deferred Income Taxes |
234 | |
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30 |
ScheduleCapitalStockAbstract Capital Stock |
250 |
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31 |
ScheduleOtherPaidInCapitalAbstract Other Paid-in Capital |
253 | |
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32 |
ScheduleCapitalStockExpenseAbstract Capital Stock Expense |
254b |
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33 |
ScheduleLongTermDebtAbstract Long-Term Debt |
256 | |
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34 |
ScheduleReconciliationOfReportedNetIncomeWithTaxableIncomeForFederalIncomeTaxesAbstract Reconciliation of Reported Net Income with Taxable Inc for Fed Inc Tax |
261 | |
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35 |
ScheduleTaxesAccruedPrepaidAndChargedDuringYearDistributionOfTaxesChargedAbstract Taxes Accrued, Prepaid and Charged During the Year |
262 | |
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36 |
ScheduleAccumulatedDeferredInvestmentTaxCreditsAbstract Accumulated Deferred Investment Tax Credits |
266 | |
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37 |
ScheduleOtherDeferredCreditsAbstract Other Deferred Credits |
269 | |
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38 |
ScheduleAccumulatedDeferredIncomeTaxesAcceleratedAmortizationPropertyAbstract Accumulated Deferred Income Taxes-Accelerated Amortization Property |
272 |
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39 |
ScheduleAccumulatedDeferredIncomeTaxesOtherPropertyAbstract Accumulated Deferred Income Taxes-Other Property |
274 | |
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40 |
ScheduleAccumulatedDeferredIncomeTaxesOtherAbstract Accumulated Deferred Income Taxes-Other |
276 | |
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41 |
ScheduleOtherRegulatoryLiabilitiesAbstract Other Regulatory Liabilities |
278 | |
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42 |
ScheduleElectricOperatingRevenuesAbstract Electric Operating Revenues |
300 | |
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43 |
ScheduleRegionalTransmissionServiceRevenuesAbstract Regional Transmission Service Revenues (Account 457.1) |
302 | |
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44 |
ScheduleSalesOfElectricityByRateSchedulesAbstract Sales of Electricity by Rate Schedules |
304 | |
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45 |
ScheduleSalesForResaleAbstract Sales for Resale |
310 | |
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46 |
ScheduleElectricOperationsAndMaintenanceExpensesAbstract Electric Operation and Maintenance Expenses |
320 | |
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47 |
SchedulePurchasedPowerAbstract Purchased Power |
326 | |
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48 |
ScheduleTransmissionOfElectricityForOthersAbstract Transmission of Electricity for Others |
328 | |
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49 |
ScheduleTransmissionOfElectricityByIsoOrRtoAbstract Transmission of Electricity by ISO/RTOs |
331 |
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50 |
ScheduleTransmissionOfElectricityByOthersAbstract Transmission of Electricity by Others |
332 | |
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51 |
ScheduleMiscellaneousGeneralExpensesAbstract Miscellaneous General Expenses-Electric |
335 | |
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52 |
ScheduleDepreciationDepletionAndAmortizationAbstract Depreciation and Amortization of Electric Plant (Account 403, 404, 405) |
336 | |
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53 |
ScheduleRegulatoryCommissionExpensesAbstract Regulatory Commission Expenses |
350 | |
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54 |
ScheduleResearchDevelopmentOrDemonstrationExpendituresAbstract Research, Development and Demonstration Activities |
352 | |
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55 |
ScheduleDistributionOfSalariesAndWagesAbstract Distribution of Salaries and Wages |
354 | |
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56 |
ScheduleCommonUtilityPlantAndExpensesAbstract Common Utility Plant and Expenses |
356 |
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57 |
ScheduleAmountsIncludedInIsoOrRtoSettlementAbstract Amounts included in ISO/RTO Settlement Statements |
397 | |
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58 |
SchedulePurchasesSalesOfAncillaryServicesAbstract Purchase and Sale of Ancillary Services |
398 | |
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59 |
ScheduleMonthlyTransmissionSystemPeakLoadAbstract Monthly Transmission System Peak Load |
400 | |
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60 |
ScheduleMonthlyIsoOrRtoTransmissionSystemPeakLoadAbstract Monthly ISO/RTO Transmission System Peak Load |
400a |
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61 |
ScheduleElectricEnergyAccountAbstract Electric Energy Account |
401a | |
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62 |
ScheduleMonthlyPeakAndOutputAbstract Monthly Peaks and Output |
401b | |
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63 |
ScheduleSteamElectricGeneratingPlantStatisticsAbstract Steam Electric Generating Plant Statistics |
402 | |
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64 |
ScheduleHydroelectricGeneratingPlantStatisticsAbstract Hydroelectric Generating Plant Statistics |
406 |
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65 |
SchedulePumpedStorageGeneratingPlantStatisticsAbstract Pumped Storage Generating Plant Statistics |
408 |
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66 |
ScheduleGeneratingPlantStatisticsAbstract Generating Plant Statistics Pages |
410 |
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66.1 |
ScheduleEnergyStorageOperationsLargePlantsAbstract Energy Storage Operations (Large Plants) |
414 |
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66.2 |
ScheduleEnergyStorageOperationsSmallPlantsAbstract Energy Storage Operations (Small Plants) |
419 |
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67 |
ScheduleTransmissionLineStatisticsAbstract Transmission Line Statistics Pages |
422 | |
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68 |
ScheduleTransmissionLinesAddedAbstract Transmission Lines Added During Year |
424 |
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69 |
ScheduleSubstationsAbstract Substations |
426 | |
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70 |
ScheduleTransactionsWithAssociatedAffiliatedCompaniesAbstract Transactions with Associated (Affiliated) Companies |
429 | |
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71 |
FootnoteDataAbstract Footnote Data |
450 |
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StockholdersReportsAbstract Stockholders' Reports (check appropriate box) |
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Stockholders' Reports Check appropriate box:
☐ Two copies will be submitted ☑ No annual report to stockholders is prepared |
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Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
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GENERAL INFORMATION |
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1. Provide name and title of officer having custody of the general corporate books of account and address of office where the general corporate books are kept, and address of office where any other corporate books of account are kept, if different from that where the general corporate books are kept.
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2. Provide the name of the State under the laws of which respondent is incorporated, and date of incorporation. If incorporated under a special law, give reference to such law. If not incorporated, state that fact and give the type of organization and the date organized.
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3. If at any time during the year the property of respondent was held by a receiver or trustee, give (a) name of receiver or trustee, (b) date such receiver or trustee took possession, (c) the authority by which the receivership or trusteeship was created, and (d) date when possession by receiver or trustee ceased.
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4. State the classes or utility and other services furnished by respondent during the year in each State in which the respondent operated.
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5. Have you engaged as the principal accountant to audit your financial statements an accountant who is not the principal accountant for your previous year's certified financial statements?
(1)
☐ Yes
(2)
☑ No |
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Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
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CONTROL OVER RESPONDENT |
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1. If any corporation, business trust, or similar organization or a combination of such organizations jointly held control over the respondent at the end of the year, state name of controlling corporation or organization, manner in which control was held, and extent of control. If control was in a holding company organization, show the chain of ownership or control to the main parent company or organization. If control was held by a trustee(s), state name of trustee(s), name of beneficiary or beneficiaries for whom trust was maintained, and purpose of the trust. |
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As of December 31, 2023, all of the common membership interests in Entergy Mississippi are held by Entergy Utility Holding Company. As of December 31, 2023, Entergy Utility Holding Company's membership interests are held by: Entergy Corporation 3.7% 459,503 shares Entergy Utility Affiliates 23.3% multiple securities Entergy Utility Assets 31.2% 3,891,055 shares Entergy Utility Enterprises 13.2% 1,640,560 shares Entergy Utility Group 2.8% 350,173 shares EUHC Holdings 24.1% 3,006,086 shares Unaffiliated third parties 1.5% multiple securities |
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Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
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CORPORATIONS CONTROLLED BY RESPONDENT |
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| Line No. |
NameOfCompanyControlledByRespondent Name of Company Controlled (a) |
CompanyControlledByRespondentKindOfBusinessDescription Kind of Business (b) |
VotingStockOwnedByRespondentPercentage Percent Voting Stock Owned (c) |
FootnoteReferences Footnote Ref. (d) |
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Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
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OFFICERS |
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| Line No. |
OfficerTitle Title (a) |
OfficerName Name of Officer (b) |
OfficerSalary Salary for Year (c) |
DateOfficerIncumbencyStarted Date Started in Period (d) |
DateOfficerIncumbencyEnded Date Ended in Period (e) |
| 1 | |||||
| 2 | (a) |
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| 3 | (b) |
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| 4 | (c) |
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| 5 | (d) |
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| 6 | (e) |
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| 7 | (f) |
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| 8 | (g) |
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| 9 | (h) |
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| 10 | (i) |
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Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: OfficerSalary |
| (b) Concept: OfficerSalary |
| (c) Concept: OfficerSalary |
| (d) Concept: OfficerSalary |
| (e) Concept: OfficerSalary |
| (f) Concept: OfficerSalary |
| (g) Concept: OfficerSalary |
| (h) Concept: OfficerSalary |
| (i) Concept: OfficerSalary |
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Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
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DIRECTORS |
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| Line No. |
NameAndTitleOfDirector Name (and Title) of Director (a) |
PrincipalBusinessAddress Principal Business Address (b) |
MemberOfTheExecutiveCommittee Member of the Executive Committee (c) |
ChairmanOfTheExecutiveCommittee Chairman of the Executive Committee (d) |
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Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
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INFORMATION ON FORMULA RATES |
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Does the respondent have formula rates? |
☑ Yes ☐ No |
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| Line No. |
RateScheduleTariffNumber FERC Rate Schedule or Tariff Number (a) |
ProceedingDocketNumber FERC Proceeding (b) |
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Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
INFORMATION ON FORMULA RATES - FERC Rate Schedule/Tariff Number FERC Proceeding |
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Does the respondent file with the Commission annual (or more frequent) filings containing the inputs to the formula rate(s)? |
☑ Yes ☐ No |
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| Line No. |
AccessionNumber Accession No. (a) |
DocumentDate Document Date / Filed Date (b) |
DocketNumber Docket No. (c) |
DescriptionOfFiling Description (d) |
RateScheduleTariffNumber Formula Rate FERC Rate Schedule Number or Tariff Number (e) |
| 1 | (a) |
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Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: DescriptionOfFiling |
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Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
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INFORMATION ON FORMULA RATES - Formula Rate Variances |
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| Line No. |
PageNumberOfFormulaRateVariances Page No(s). (a) |
ScheduleOfFormulaRateVariances Schedule (b) |
ColumnOfFormulaRateVariances Column (c) |
LineNumberOfFormulaRateVariances Line No. (d) |
| 1 | ||||
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Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
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IMPORTANT CHANGES DURING THE QUARTER/YEAR |
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Give particulars (details) concerning the matters indicated below. Make the statements explicit and precise, and number them in accordance with the inquiries. Each inquiry should be answered. Enter "none," "not applicable," or "NA" where applicable. If information which answers an inquiry is given elsewhere in the report, make a reference to the schedule in which it appears.
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Fossil operating employees are represented by the International Brotherhood of Electrical Workers AFL-CIO, Local Unions 605 and 985. The Company and the Union agreed to a contract effective April 16, 2022 through April 16, 2026. Effective April 16, 2023, the wage increase was 2.5%. Effective April 1, 2023, executive and senior management, middle management, professionals, and non-represented operating, maintenance, and support staff pay increases averaged approximately 4.0%. |
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Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
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COMPARATIVE BALANCE SHEET (ASSETS AND OTHER DEBITS) |
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| Line No. |
Title of Account (a) |
Ref. Page No. (b) |
Current Year End of Quarter/Year Balance (c) |
Prior Year End Balance 12/31 (d) |
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1 |
UtilityPlantAbstract UTILITY PLANT |
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2 |
UtilityPlant Utility Plant (101-106, 114) |
200 |
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3 |
ConstructionWorkInProgress Construction Work in Progress (107) |
200 |
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4 |
UtilityPlantAndConstructionWorkInProgress TOTAL Utility Plant (Enter Total of lines 2 and 3) |
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5 |
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility (Less) Accum. Prov. for Depr. Amort. Depl. (108, 110, 111, 115) |
200 |
(a) |
(b) |
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6 |
UtilityPlantNet Net Utility Plant (Enter Total of line 4 less 5) |
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7 |
NuclearFuelInProcessOfRefinementConversionEnrichmentAndFabrication Nuclear Fuel in Process of Ref., Conv., Enrich., and Fab. (120.1) |
202 |
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8 |
NuclearFuelMaterialsAndAssembliesStockAccountMajorOnly Nuclear Fuel Materials and Assemblies-Stock Account (120.2) |
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9 |
NuclearFuelAssembliesInReactorMajorOnly Nuclear Fuel Assemblies in Reactor (120.3) |
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10 |
SpentNuclearFuelMajorOnly Spent Nuclear Fuel (120.4) |
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11 |
NuclearFuelUnderCapitalLeases Nuclear Fuel Under Capital Leases (120.6) |
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12 |
AccumulatedProvisionForAmortizationOfNuclearFuelAssemblies (Less) Accum. Prov. for Amort. of Nucl. Fuel Assemblies (120.5) |
202 |
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13 |
NuclearFuelNet Net Nuclear Fuel (Enter Total of lines 7-11 less 12) |
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14 |
UtilityPlantAndNuclearFuelNet Net Utility Plant (Enter Total of lines 6 and 13) |
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15 |
OtherElectricPlantAdjustments Utility Plant Adjustments (116) |
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16 |
GasStoredUndergroundNoncurrent Gas Stored Underground - Noncurrent (117) |
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17 |
OtherPropertyAndInvestmentsAbstract OTHER PROPERTY AND INVESTMENTS |
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18 |
NonutilityProperty Nonutility Property (121) |
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19 |
AccumulatedProvisionForDepreciationAndAmortizationOfNonutilityProperty (Less) Accum. Prov. for Depr. and Amort. (122) |
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20 |
InvestmentInAssociatedCompanies Investments in Associated Companies (123) |
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21 |
InvestmentInSubsidiaryCompanies Investment in Subsidiary Companies (123.1) |
224 |
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23 |
NoncurrentPortionOfAllowances Noncurrent Portion of Allowances |
228 |
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24 |
OtherInvestments Other Investments (124) |
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25 |
SinkingFunds Sinking Funds (125) |
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26 |
DepreciationFund Depreciation Fund (126) |
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27 |
AmortizationFundFederal Amortization Fund - Federal (127) |
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28 |
OtherSpecialFunds Other Special Funds (128) |
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29 |
SpecialFunds Special Funds (Non Major Only) (129) |
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30 |
DerivativeInstrumentAssetsLongTerm Long-Term Portion of Derivative Assets (175) |
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31 |
DerivativeInstrumentAssetsHedgesLongTerm Long-Term Portion of Derivative Assets - Hedges (176) |
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32 |
OtherPropertyAndInvestments TOTAL Other Property and Investments (Lines 18-21 and 23-31) |
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33 |
CurrentAndAccruedAssetsAbstract CURRENT AND ACCRUED ASSETS |
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34 |
CashAndWorkingFunds Cash and Working Funds (Non-major Only) (130) |
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35 |
Cash Cash (131) |
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36 |
SpecialDeposits Special Deposits (132-134) |
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37 |
WorkingFunds Working Fund (135) |
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38 |
TemporaryCashInvestments Temporary Cash Investments (136) |
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39 |
NotesReceivable Notes Receivable (141) |
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40 |
CustomerAccountsReceivable Customer Accounts Receivable (142) |
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41 |
OtherAccountsReceivable Other Accounts Receivable (143) |
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42 |
AccumulatedProvisionForUncollectibleAccountsCredit (Less) Accum. Prov. for Uncollectible Acct.-Credit (144) |
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43 |
NotesReceivableFromAssociatedCompanies Notes Receivable from Associated Companies (145) |
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44 |
AccountsReceivableFromAssociatedCompanies Accounts Receivable from Assoc. Companies (146) |
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45 |
FuelStock Fuel Stock (151) |
227 |
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46 |
FuelStockExpensesUndistributed Fuel Stock Expenses Undistributed (152) |
227 |
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47 |
Residuals Residuals (Elec) and Extracted Products (153) |
227 |
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48 |
PlantMaterialsAndOperatingSupplies Plant Materials and Operating Supplies (154) |
227 |
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49 |
Merchandise Merchandise (155) |
227 |
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50 |
OtherMaterialsAndSupplies Other Materials and Supplies (156) |
227 |
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51 |
NuclearMaterialsHeldForSale Nuclear Materials Held for Sale (157) |
202/227 |
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52 |
AllowanceInventoryAndWithheld Allowances (158.1 and 158.2) |
228 |
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53 |
NoncurrentPortionOfAllowances (Less) Noncurrent Portion of Allowances |
228 |
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54 |
StoresExpenseUndistributed Stores Expense Undistributed (163) |
227 |
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55 |
GasStoredCurrent Gas Stored Underground - Current (164.1) |
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56 |
LiquefiedNaturalGasStoredAndHeldForProcessing Liquefied Natural Gas Stored and Held for Processing (164.2-164.3) |
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57 |
Prepayments Prepayments (165) |
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58 |
AdvancesForGas Advances for Gas (166-167) |
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59 |
InterestAndDividendsReceivable Interest and Dividends Receivable (171) |
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|
60 |
RentsReceivable Rents Receivable (172) |
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|
61 |
AccruedUtilityRevenues Accrued Utility Revenues (173) |
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|
62 |
MiscellaneousCurrentAndAccruedAssets Miscellaneous Current and Accrued Assets (174) |
|
|
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|
63 |
DerivativeInstrumentAssets Derivative Instrument Assets (175) |
|
|
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|
64 |
DerivativeInstrumentAssetsLongTerm (Less) Long-Term Portion of Derivative Instrument Assets (175) |
|||
|
65 |
DerivativeInstrumentAssetsHedges Derivative Instrument Assets - Hedges (176) |
|||
|
66 |
DerivativeInstrumentAssetsHedgesLongTerm (Less) Long-Term Portion of Derivative Instrument Assets - Hedges (176) |
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|
67 |
CurrentAndAccruedAssets Total Current and Accrued Assets (Lines 34 through 66) |
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|
68 |
DeferredDebitsAbstract DEFERRED DEBITS |
|||
|
69 |
UnamortizedDebtExpense Unamortized Debt Expenses (181) |
|
|
|
|
70 |
ExtraordinaryPropertyLosses Extraordinary Property Losses (182.1) |
230a |
||
|
71 |
UnrecoveredPlantAndRegulatoryStudyCosts Unrecovered Plant and Regulatory Study Costs (182.2) |
230b |
||
|
72 |
OtherRegulatoryAssets Other Regulatory Assets (182.3) |
232 |
|
|
|
73 |
PreliminarySurveyAndInvestigationCharges Prelim. Survey and Investigation Charges (Electric) (183) |
|
|
|
|
74 |
PreliminaryNaturalGasSurveyAndInvestigationChargesAndOtherPreliminarySurveyAndInvestigationCharges Preliminary Natural Gas Survey and Investigation Charges 183.1) |
|||
|
75 |
OtherPreliminarySurveyAndInvestigationCharges Other Preliminary Survey and Investigation Charges (183.2) |
|||
|
76 |
ClearingAccounts Clearing Accounts (184) |
|
|
|
|
77 |
TemporaryFacilities Temporary Facilities (185) |
|||
|
78 |
MiscellaneousDeferredDebits Miscellaneous Deferred Debits (186) |
233 |
|
|
|
79 |
DeferredLossesFromDispositionOfUtilityPlant Def. Losses from Disposition of Utility Plt. (187) |
|||
|
80 |
ResearchDevelopmentAndDemonstrationExpenditures Research, Devel. and Demonstration Expend. (188) |
352 |
||
|
81 |
UnamortizedLossOnReacquiredDebt Unamortized Loss on Reaquired Debt (189) |
|
|
|
|
82 |
AccumulatedDeferredIncomeTaxes Accumulated Deferred Income Taxes (190) |
234 |
|
|
|
83 |
UnrecoveredPurchasedGasCosts Unrecovered Purchased Gas Costs (191) |
|||
|
84 |
DeferredDebits Total Deferred Debits (lines 69 through 83) |
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|
85 |
AssetsAndOtherDebits TOTAL ASSETS (lines 14-16, 32, 67, and 84) |
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Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility |
| (b) Concept: AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility |
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
COMPARATIVE BALANCE SHEET (LIABILITIES AND OTHER CREDITS) |
||||
| Line No. |
Title of Account (a) |
Ref. Page No. (b) |
Current Year End of Quarter/Year Balance (c) |
Prior Year End Balance 12/31 (d) |
|
1 |
ProprietaryCapitalAbstract PROPRIETARY CAPITAL |
|||
|
2 |
CommonStockIssued Common Stock Issued (201) |
250 |
||
|
3 |
PreferredStockIssued Preferred Stock Issued (204) |
250 |
||
|
4 |
CapitalStockSubscribed Capital Stock Subscribed (202, 205) |
|||
|
5 |
StockLiabilityForConversion Stock Liability for Conversion (203, 206) |
|||
|
6 |
PremiumOnCapitalStock Premium on Capital Stock (207) |
|||
|
7 |
OtherPaidInCapital Other Paid-In Capital (208-211) |
253 |
|
|
|
8 |
InstallmentsReceivedOnCapitalStock Installments Received on Capital Stock (212) |
252 |
||
|
9 |
DiscountOnCapitalStock (Less) Discount on Capital Stock (213) |
254 |
||
|
10 |
CapitalStockExpense (Less) Capital Stock Expense (214) |
254b |
||
|
11 |
RetainedEarnings Retained Earnings (215, 215.1, 216) |
118 |
|
|
|
12 |
UnappropriatedUndistributedSubsidiaryEarnings Unappropriated Undistributed Subsidiary Earnings (216.1) |
118 |
|
|
|
13 |
ReacquiredCapitalStock (Less) Reacquired Capital Stock (217) |
250 |
||
|
14 |
NoncorporateProprietorship Noncorporate Proprietorship (Non-major only) (218) |
|||
|
15 |
AccumulatedOtherComprehensiveIncome Accumulated Other Comprehensive Income (219) |
122(a)(b) |
||
|
16 |
ProprietaryCapital Total Proprietary Capital (lines 2 through 15) |
|
|
|
|
17 |
LongTermDebtAbstract LONG-TERM DEBT |
|||
|
18 |
Bonds Bonds (221) |
256 |
|
|
|
19 |
ReacquiredBonds (Less) Reacquired Bonds (222) |
256 |
||
|
20 |
AdvancesFromAssociatedCompanies Advances from Associated Companies (223) |
256 |
||
|
21 |
OtherLongTermDebt Other Long-Term Debt (224) |
256 |
|
|
|
22 |
UnamortizedPremiumOnLongTermDebt Unamortized Premium on Long-Term Debt (225) |
|
|
|
|
23 |
UnamortizedDiscountOnLongTermDebtDebit (Less) Unamortized Discount on Long-Term Debt-Debit (226) |
|
|
|
|
24 |
LongTermDebt Total Long-Term Debt (lines 18 through 23) |
|
|
|
|
25 |
OtherNoncurrentLiabilitiesAbstract OTHER NONCURRENT LIABILITIES |
|||
|
26 |
ObligationsUnderCapitalLeaseNoncurrent Obligations Under Capital Leases - Noncurrent (227) |
|
|
|
|
27 |
AccumulatedProvisionForPropertyInsurance Accumulated Provision for Property Insurance (228.1) |
|
|
|
|
28 |
AccumulatedProvisionForInjuriesAndDamages Accumulated Provision for Injuries and Damages (228.2) |
|
|
|
|
29 |
AccumulatedProvisionForPensionsAndBenefits Accumulated Provision for Pensions and Benefits (228.3) |
|
|
|
|
30 |
AccumulatedMiscellaneousOperatingProvisions Accumulated Miscellaneous Operating Provisions (228.4) |
|
|
|
|
31 |
AccumulatedProvisionForRateRefunds Accumulated Provision for Rate Refunds (229) |
|||
|
32 |
LongTermPortionOfDerivativeInstrumentLiabilities Long-Term Portion of Derivative Instrument Liabilities |
|||
|
33 |
LongTermPortionOfDerivativeInstrumentLiabilitiesHedges Long-Term Portion of Derivative Instrument Liabilities - Hedges |
|||
|
34 |
AssetRetirementObligations Asset Retirement Obligations (230) |
|
|
|
|
35 |
OtherNoncurrentLiabilities Total Other Noncurrent Liabilities (lines 26 through 34) |
|
|
|
|
36 |
CurrentAndAccruedLiabilitiesAbstract CURRENT AND ACCRUED LIABILITIES |
|||
|
37 |
NotesPayable Notes Payable (231) |
|||
|
38 |
AccountsPayable Accounts Payable (232) |
|
|
|
|
39 |
NotesPayableToAssociatedCompanies Notes Payable to Associated Companies (233) |
|||
|
40 |
AccountsPayableToAssociatedCompanies Accounts Payable to Associated Companies (234) |
|
|
|
|
41 |
CustomerDeposits Customer Deposits (235) |
|
|
|
|
42 |
TaxesAccrued Taxes Accrued (236) |
262 |
|
|
|
43 |
InterestAccrued Interest Accrued (237) |
|
|
|
|
44 |
DividendsDeclared Dividends Declared (238) |
|||
|
45 |
MaturedLongTermDebt Matured Long-Term Debt (239) |
|||
|
46 |
MaturedInterest Matured Interest (240) |
|||
|
47 |
TaxCollectionsPayable Tax Collections Payable (241) |
|
|
|
|
48 |
MiscellaneousCurrentAndAccruedLiabilities Miscellaneous Current and Accrued Liabilities (242) |
|
|
|
|
49 |
ObligationsUnderCapitalLeasesCurrent Obligations Under Capital Leases-Current (243) |
|
|
|
|
50 |
DerivativesInstrumentLiabilities Derivative Instrument Liabilities (244) |
|
|
|
|
51 |
LongTermPortionOfDerivativeInstrumentLiabilities (Less) Long-Term Portion of Derivative Instrument Liabilities |
|||
|
52 |
DerivativeInstrumentLiabilitiesHedges Derivative Instrument Liabilities - Hedges (245) |
|||
|
53 |
LongTermPortionOfDerivativeInstrumentLiabilitiesHedges (Less) Long-Term Portion of Derivative Instrument Liabilities-Hedges |
|||
|
54 |
CurrentAndAccruedLiabilities Total Current and Accrued Liabilities (lines 37 through 53) |
|
|
|
|
55 |
DeferredCreditsAbstract DEFERRED CREDITS |
|||
|
56 |
CustomerAdvancesForConstruction Customer Advances for Construction (252) |
|
|
|
|
57 |
AccumulatedDeferredInvestmentTaxCredits Accumulated Deferred Investment Tax Credits (255) |
266 |
|
|
|
58 |
DeferredGainsFromDispositionOfUtilityPlant Deferred Gains from Disposition of Utility Plant (256) |
|||
|
59 |
OtherDeferredCredits Other Deferred Credits (253) |
269 |
|
|
|
60 |
OtherRegulatoryLiabilities Other Regulatory Liabilities (254) |
278 |
|
|
|
61 |
UnamortizedGainOnReacquiredDebt Unamortized Gain on Reacquired Debt (257) |
|||
|
62 |
AccumulatedDeferredIncomeTaxesAcceleratedAmortizationProperty Accum. Deferred Income Taxes-Accel. Amort.(281) |
272 |
||
|
63 |
AccumulatedDeferredIncomeTaxesOtherProperty Accum. Deferred Income Taxes-Other Property (282) |
|
|
|
|
64 |
AccumulatedDeferredIncomeTaxesOther Accum. Deferred Income Taxes-Other (283) |
|
|
|
|
65 |
DeferredCredits Total Deferred Credits (lines 56 through 64) |
|
|
|
|
66 |
LiabilitiesAndOtherCredits TOTAL LIABILITIES AND STOCKHOLDER EQUITY (lines 16, 24, 35, 54 and 65) |
|
|
|
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
STATEMENT OF INCOME |
|||||||||||||
|
Quarterly
Annual or Quarterly if applicable
|
|||||||||||||
| Line No. |
Title of Account (a) |
(Ref.) Page No. (b) |
Total Current Year to Date Balance for Quarter/Year (c) |
Total Prior Year to Date Balance for Quarter/Year (d) |
Current 3 Months Ended - Quarterly Only - No 4th Quarter (e) |
Prior 3 Months Ended - Quarterly Only - No 4th Quarter (f) |
Electric Utility Current Year to Date (in dollars) (g) |
Electric Utility Previous Year to Date (in dollars) (h) |
Gas Utiity Current Year to Date (in dollars) (i) |
Gas Utility Previous Year to Date (in dollars) (j) |
Other Utility Current Year to Date (in dollars) (k) |
Other Utility Previous Year to Date (in dollars) (l) |
|
|
1 |
UtilityOperatingIncomeAbstract UTILITY OPERATING INCOME |
||||||||||||
|
2 |
OperatingRevenues Operating Revenues (400) |
300 |
|
|
|
|
|||||||
|
3 |
OperatingExpensesAbstract Operating Expenses |
||||||||||||
|
4 |
OperationExpense Operation Expenses (401) |
320 |
|
|
|
|
|||||||
|
5 |
MaintenanceExpense Maintenance Expenses (402) |
320 |
|
|
|
|
|||||||
|
6 |
DepreciationExpense Depreciation Expense (403) |
336 |
|
|
|
|
|||||||
|
7 |
DepreciationExpenseForAssetRetirementCosts Depreciation Expense for Asset Retirement Costs (403.1) |
336 |
|
|
|
|
|||||||
|
8 |
AmortizationAndDepletionOfUtilityPlant Amort. & Depl. of Utility Plant (404-405) |
336 |
|
|
|
|
|||||||
|
9 |
AmortizationOfElectricPlantAcquisitionAdjustments Amort. of Utility Plant Acq. Adj. (406) |
336 |
|
|
|
|
|||||||
|
10 |
AmortizationOfPropertyLossesUnrecoveredPlantAndRegulatoryStudyCosts Amort. Property Losses, Unrecov Plant and Regulatory Study Costs (407) |
||||||||||||
|
11 |
AmortizationOfConversionExpenses Amort. of Conversion Expenses (407.2) |
||||||||||||
|
12 |
RegulatoryDebits Regulatory Debits (407.3) |
|
|
|
|
||||||||
|
13 |
RegulatoryCredits (Less) Regulatory Credits (407.4) |
|
|
|
|
||||||||
|
14 |
TaxesOtherThanIncomeTaxesUtilityOperatingIncome Taxes Other Than Income Taxes (408.1) |
262 |
|
|
|
|
|||||||
|
15 |
IncomeTaxesOperatingIncome Income Taxes - Federal (409.1) |
262 |
|
|
|
|
|||||||
|
16 |
IncomeTaxesUtilityOperatingIncomeOther Income Taxes - Other (409.1) |
262 |
|
|
|
|
|||||||
|
17 |
ProvisionsForDeferredIncomeTaxesUtilityOperatingIncome Provision for Deferred Income Taxes (410.1) |
234, 272 |
|
|
|
|
|||||||
|
18 |
ProvisionForDeferredIncomeTaxesCreditOperatingIncome (Less) Provision for Deferred Income Taxes-Cr. (411.1) |
234, 272 |
|
|
|
|
|||||||
|
19 |
InvestmentTaxCreditAdjustments Investment Tax Credit Adj. - Net (411.4) |
266 |
|
|
|
|
|||||||
|
20 |
GainsFromDispositionOfPlant (Less) Gains from Disp. of Utility Plant (411.6) |
||||||||||||
|
21 |
LossesFromDispositionOfServiceCompanyPlant Losses from Disp. of Utility Plant (411.7) |
||||||||||||
|
22 |
GainsFromDispositionOfAllowances (Less) Gains from Disposition of Allowances (411.8) |
|
|
||||||||||
|
23 |
LossesFromDispositionOfAllowances Losses from Disposition of Allowances (411.9) |
||||||||||||
|
24 |
AccretionExpense Accretion Expense (411.10) |
|
|
|
|
||||||||
|
25 |
UtilityOperatingExpenses TOTAL Utility Operating Expenses (Enter Total of lines 4 thru 24) |
|
|
|
|
||||||||
|
27 |
NetUtilityOperatingIncome Net Util Oper Inc (Enter Tot line 2 less 25) |
|
|
|
|
||||||||
|
28 |
OtherIncomeAndDeductionsAbstract Other Income and Deductions |
||||||||||||
|
29 |
OtherIncomeAbstract Other Income |
||||||||||||
|
30 |
NonutilityOperatingIncomeAbstract Nonutilty Operating Income |
||||||||||||
|
31 |
RevenuesFromMerchandisingJobbingAndContractWork Revenues From Merchandising, Jobbing and Contract Work (415) |
||||||||||||
|
32 |
CostsAndExpensesOfMerchandisingJobbingAndContractWork (Less) Costs and Exp. of Merchandising, Job. & Contract Work (416) |
||||||||||||
|
33 |
RevenuesFromNonutilityOperations Revenues From Nonutility Operations (417) |
||||||||||||
|
34 |
ExpensesOfNonutilityOperations (Less) Expenses of Nonutility Operations (417.1) |
|
|
||||||||||
|
35 |
NonoperatingRentalIncome Nonoperating Rental Income (418) |
||||||||||||
|
36 |
EquityInEarningsOfSubsidiaryCompanies Equity in Earnings of Subsidiary Companies (418.1) |
119 |
|
|
|||||||||
|
37 |
InterestAndDividendIncome Interest and Dividend Income (419) |
|
|
||||||||||
|
38 |
AllowanceForOtherFundsUsedDuringConstruction Allowance for Other Funds Used During Construction (419.1) |
|
|
||||||||||
|
39 |
MiscellaneousNonoperatingIncome Miscellaneous Nonoperating Income (421) |
|
|
||||||||||
|
40 |
GainOnDispositionOfProperty Gain on Disposition of Property (421.1) |
|
|||||||||||
|
41 |
OtherIncome TOTAL Other Income (Enter Total of lines 31 thru 40) |
|
|
||||||||||
|
42 |
OtherIncomeDeductionsAbstract Other Income Deductions |
||||||||||||
|
43 |
LossOnDispositionOfProperty Loss on Disposition of Property (421.2) |
|
|
||||||||||
|
44 |
MiscellaneousAmortization Miscellaneous Amortization (425) |
||||||||||||
|
45 |
Donations Donations (426.1) |
|
|
||||||||||
|
46 |
LifeInsurance Life Insurance (426.2) |
||||||||||||
|
47 |
Penalties Penalties (426.3) |
|
|
||||||||||
|
48 |
ExpendituresForCertainCivicPoliticalAndRelatedActivities Exp. for Certain Civic, Political & Related Activities (426.4) |
|
|
||||||||||
|
49 |
OtherDeductions Other Deductions (426.5) |
|
|
||||||||||
|
50 |
OtherIncomeDeductions TOTAL Other Income Deductions (Total of lines 43 thru 49) |
|
|
||||||||||
|
51 |
TaxesApplicableToOtherIncomeAndDeductionsAbstract Taxes Applic. to Other Income and Deductions |
||||||||||||
|
52 |
TaxesOtherThanIncomeTaxesOtherIncomeAndDeductions Taxes Other Than Income Taxes (408.2) |
262 |
|
||||||||||
|
53 |
IncomeTaxesFederal Income Taxes-Federal (409.2) |
262 |
|
|
|||||||||
|
54 |
IncomeTaxesOther Income Taxes-Other (409.2) |
262 |
|
|
|||||||||
|
55 |
ProvisionForDeferredIncomeTaxesOtherIncomeAndDeductions Provision for Deferred Inc. Taxes (410.2) |
234, 272 |
|||||||||||
|
56 |
ProvisionForDeferredIncomeTaxesCreditOtherIncomeAndDeductions (Less) Provision for Deferred Income Taxes-Cr. (411.2) |
234, 272 |
|||||||||||
|
57 |
InvestmentTaxCreditAdjustmentsNonutilityOperations Investment Tax Credit Adj.-Net (411.5) |
||||||||||||
|
58 |
InvestmentTaxCredits (Less) Investment Tax Credits (420) |
||||||||||||
|
59 |
TaxesOnOtherIncomeAndDeductions TOTAL Taxes on Other Income and Deductions (Total of lines 52-58) |
|
|
||||||||||
|
60 |
NetOtherIncomeAndDeductions Net Other Income and Deductions (Total of lines 41, 50, 59) |
|
|
||||||||||
|
61 |
InterestChargesAbstract Interest Charges |
||||||||||||
|
62 |
InterestOnLongTermDebt Interest on Long-Term Debt (427) |
|
|
||||||||||
|
63 |
AmortizationOfDebtDiscountAndExpense Amort. of Debt Disc. and Expense (428) |
|
|
||||||||||
|
64 |
AmortizationOfLossOnReacquiredDebt Amortization of Loss on Reaquired Debt (428.1) |
|
|
||||||||||
|
65 |
AmortizationOfPremiumOnDebtCredit (Less) Amort. of Premium on Debt-Credit (429) |
|
|
||||||||||
|
66 |
AmortizationOfGainOnReacquiredDebtCredit (Less) Amortization of Gain on Reaquired Debt-Credit (429.1) |
||||||||||||
|
67 |
InterestOnDebtToAssociatedCompanies Interest on Debt to Assoc. Companies (430) |
|
|
||||||||||
|
68 |
OtherInterestExpense Other Interest Expense (431) |
|
|
||||||||||
|
69 |
AllowanceForBorrowedFundsUsedDuringConstructionCredit (Less) Allowance for Borrowed Funds Used During Construction-Cr. (432) |
|
|
||||||||||
|
70 |
NetInterestCharges Net Interest Charges (Total of lines 62 thru 69) |
|
|
||||||||||
|
71 |
IncomeBeforeExtraordinaryItems Income Before Extraordinary Items (Total of lines 27, 60 and 70) |
|
|
||||||||||
|
72 |
ExtraordinaryItemsAbstract Extraordinary Items |
||||||||||||
|
73 |
ExtraordinaryIncome Extraordinary Income (434) |
||||||||||||
|
74 |
ExtraordinaryDeductions (Less) Extraordinary Deductions (435) |
||||||||||||
|
75 |
NetExtraordinaryItems Net Extraordinary Items (Total of line 73 less line 74) |
||||||||||||
|
76 |
IncomeTaxesExtraordinaryItems Income Taxes-Federal and Other (409.3) |
262 |
|
||||||||||
|
77 |
ExtraordinaryItemsAfterTaxes Extraordinary Items After Taxes (line 75 less line 76) |
||||||||||||
|
78 |
NetIncomeLoss Net Income (Total of line 71 and 77) |
|
|
||||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
STATEMENT OF RETAINED EARNINGS |
||||
|
||||
| Line No. |
Item (a) |
Contra Primary Account Affected (b) |
Current Quarter/Year Year to Date Balance (c) |
Previous Quarter/Year Year to Date Balance (d) |
|
UnappropriatedRetainedEarningsAbstract UNAPPROPRIATED RETAINED EARNINGS (Account 216) |
||||
|
1 |
UnappropriatedRetainedEarnings Balance-Beginning of Period |
|
|
|
|
2 |
ChangesAbstract Changes |
|||
|
3 |
AdjustmentsToRetainedEarningsAbstract Adjustments to Retained Earnings (Account 439) |
|||
|
4 |
AdjustmentsToRetainedEarningsCreditAbstract Adjustments to Retained Earnings Credit |
|||
|
9 |
AdjustmentsToRetainedEarningsCredit TOTAL Credits to Retained Earnings (Acct. 439) |
|||
|
10 |
AdjustmentsToRetainedEarningsDebitAbstract Adjustments to Retained Earnings Debit |
|||
|
15 |
AdjustmentsToRetainedEarningsDebit TOTAL Debits to Retained Earnings (Acct. 439) |
|||
|
16 |
BalanceTransferredFromIncome Balance Transferred from Income (Account 433 less Account 418.1) |
|
|
|
|
17 |
AppropriationsOfRetainedEarningsAbstract Appropriations of Retained Earnings (Acct. 436) |
|||
|
22 |
AppropriationsOfRetainedEarnings TOTAL Appropriations of Retained Earnings (Acct. 436) |
|||
|
23 |
DividendsDeclaredPreferredStockAbstract Dividends Declared-Preferred Stock (Account 437) |
|||
|
29 |
DividendsDeclaredPreferredStock TOTAL Dividends Declared-Preferred Stock (Acct. 437) |
|||
|
30 |
DividendsDeclaredCommonStockAbstract Dividends Declared-Common Stock (Account 438) |
|||
|
30.1 |
DividendsDeclaredCommonStock |
|
|
|
|
36 |
DividendsDeclaredCommonStock TOTAL Dividends Declared-Common Stock (Acct. 438) |
|
||
|
37 |
TransfersFromUnappropriatedUndistributedSubsidiaryEarnings Transfers from Acct 216.1, Unapprop. Undistrib. Subsidiary Earnings |
|||
|
38 |
UnappropriatedRetainedEarnings Balance - End of Period (Total 1,9,15,16,22,29,36,37) |
|
|
|
|
39 |
AppropriatedRetainedEarningsAbstract APPROPRIATED RETAINED EARNINGS (Account 215) |
|||
|
45 |
AppropriatedRetainedEarnings TOTAL Appropriated Retained Earnings (Account 215) |
|||
|
AppropriatedRetainedEarningsAmortizationReserveFederalAbstract APPROP. RETAINED EARNINGS - AMORT. Reserve, Federal (Account 215.1) |
||||
|
46 |
AppropriatedRetainedEarningsAmortizationReserveFederal TOTAL Approp. Retained Earnings-Amort. Reserve, Federal (Acct. 215.1) |
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47 |
AppropriatedRetainedEarningsIncludingReserveAmortization TOTAL Approp. Retained Earnings (Acct. 215, 215.1) (Total 45,46) |
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48 |
RetainedEarnings TOTAL Retained Earnings (Acct. 215, 215.1, 216) (Total 38, 47) (216.1) |
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UnappropriatedUndistributedSubsidiaryEarningsAbstract UNAPPROPRIATED UNDISTRIBUTED SUBSIDIARY EARNINGS (Account Report only on an Annual Basis, no Quarterly) |
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49 |
UnappropriatedUndistributedSubsidiaryEarnings Balance-Beginning of Year (Debit or Credit) |
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50 |
EquityInEarningsOfSubsidiaryCompanies Equity in Earnings for Year (Credit) (Account 418.1) |
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51 |
DividendsReceived (Less) Dividends Received (Debit) |
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52 |
ChangesUnappropriatedUndistributedSubsidiaryEarningsCredits TOTAL other Changes in unappropriated undistributed subsidiary earnings for the year |
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53 |
UnappropriatedUndistributedSubsidiaryEarnings Balance-End of Year (Total lines 49 thru 52) |
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Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
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STATEMENT OF CASH FLOWS |
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| Line No. |
Description (See Instructions No.1 for explanation of codes) (a) |
Current Year to Date Quarter/Year (b) |
Previous Year to Date Quarter/Year (c) |
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1 |
NetCashFlowFromOperatingActivitiesAbstract Net Cash Flow from Operating Activities |
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2 |
NetIncomeLoss Net Income (Line 78(c) on page 117) |
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3 |
NoncashChargesCreditsToIncomeAbstract Noncash Charges (Credits) to Income: |
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4 |
DepreciationAndDepletion Depreciation and Depletion |
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5 |
NoncashAdjustmentsToCashFlowsFromOperatingActivities Amortization of (Specify) (footnote details) |
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5.1 |
NoncashAdjustmentsToCashFlowsFromOperatingActivitiesDescription |
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8 |
DeferredIncomeTaxesNet Deferred Income Taxes (Net) |
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9 |
InvestmentTaxCreditAdjustmentsNet Investment Tax Credit Adjustment (Net) |
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10 |
NetIncreaseDecreaseInReceivablesOperatingActivities Net (Increase) Decrease in Receivables |
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11 |
NetIncreaseDecreaseInInventoryOperatingActivities Net (Increase) Decrease in Inventory |
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12 |
NetIncreaseDecreaseInAllowancesInventoryOperatingActivities Net (Increase) Decrease in Allowances Inventory |
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13 |
NetIncreaseDecreaseInPayablesAndAccruedExpensesOperatingActivities Net Increase (Decrease) in Payables and Accrued Expenses |
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14 |
NetIncreaseDecreaseInOtherRegulatoryAssetsOperatingActivities Net (Increase) Decrease in Other Regulatory Assets |
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15 |
NetIncreaseDecreaseInOtherRegulatoryLiabilitiesOperatingActivities Net Increase (Decrease) in Other Regulatory Liabilities |
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16 |
AllowanceForOtherFundsUsedDuringConstructionOperatingActivities (Less) Allowance for Other Funds Used During Construction |
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17 |
UndistributedEarningsFromSubsidiaryCompaniesOperatingActivities (Less) Undistributed Earnings from Subsidiary Companies |
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18 |
OtherAdjustmentsToCashFlowsFromOperatingActivities Other (provide details in footnote): |
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18.1 |
OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription |
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18.2 |
OtherAdjustmentsToCashFlowsFromOperatingActivitiesDescription |
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22 |
NetCashFlowFromOperatingActivities Net Cash Provided by (Used in) Operating Activities (Total of Lines 2 thru 21) |
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24 |
CashFlowsFromInvestmentActivitiesAbstract Cash Flows from Investment Activities: |
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25 |
ConstructionAndAcquisitionOfPlantIncludingLandAbstract Construction and Acquisition of Plant (including land): |
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26 |
GrossAdditionsToUtilityPlantLessNuclearFuelInvestingActivities Gross Additions to Utility Plant (less nuclear fuel) |
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27 |
GrossAdditionsToNuclearFuelInvestingActivities Gross Additions to Nuclear Fuel |
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28 |
GrossAdditionsToCommonUtilityPlantInvestingActivities Gross Additions to Common Utility Plant |
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29 |
GrossAdditionsToNonutilityPlantInvestingActivities Gross Additions to Nonutility Plant |
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30 |
AllowanceForOtherFundsUsedDuringConstructionInvestingActivities (Less) Allowance for Other Funds Used During Construction |
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31 |
OtherConstructionAndAcquisitionOfPlantInvestmentActivities Other (provide details in footnote): |
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34 |
CashOutflowsForPlant Cash Outflows for Plant (Total of lines 26 thru 33) |
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36 |
AcquisitionOfOtherNoncurrentAssets Acquisition of Other Noncurrent Assets (d) |
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37 |
ProceedsFromDisposalOfNoncurrentAssets Proceeds from Disposal of Noncurrent Assets (d) |
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39 |
InvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompanies Investments in and Advances to Assoc. and Subsidiary Companies |
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40 |
ContributionsAndAdvancesFromAssociatedAndSubsidiaryCompanies Contributions and Advances from Assoc. and Subsidiary Companies |
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41 |
DispositionOfInvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompaniesAbstract Disposition of Investments in (and Advances to) |
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42 |
DispositionOfInvestmentsInAndAdvancesToAssociatedAndSubsidiaryCompanies Disposition of Investments in (and Advances to) Associated and Subsidiary Companies |
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44 |
PurchaseOfInvestmentSecurities Purchase of Investment Securities (a) |
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45 |
ProceedsFromSalesOfInvestmentSecurities Proceeds from Sales of Investment Securities (a) |
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46 |
LoansMadeOrPurchased Loans Made or Purchased |
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47 |
CollectionsOnLoans Collections on Loans |
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49 |
NetIncreaseDecreaseInReceivablesInvestingActivities Net (Increase) Decrease in Receivables |
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50 |
NetIncreaseDecreaseInInventoryInvestingActivities Net (Increase) Decrease in Inventory |
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51 |
NetIncreaseDecreaseInAllowancesHeldForSpeculationInvestingActivities Net (Increase) Decrease in Allowances Held for Speculation |
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52 |
NetIncreaseDecreaseInPayablesAndAccruedExpensesInvestingActivities Net Increase (Decrease) in Payables and Accrued Expenses |
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53 |
OtherAdjustmentsToCashFlowsFromInvestmentActivities Other (provide details in footnote): |
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53.1 |
OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription |
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53.2 |
OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription |
(a) |
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53.3 |
OtherAdjustmentsToCashFlowsFromInvestmentActivitiesDescription |
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57 |
CashFlowsProvidedFromUsedInInvestmentActivities Net Cash Provided by (Used in) Investing Activities (Total of lines 34 thru 55) |
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59 |
CashFlowsFromFinancingActivitiesAbstract Cash Flows from Financing Activities: |
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60 |
ProceedsFromIssuanceAbstract Proceeds from Issuance of: |
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61 |
ProceedsFromIssuanceOfLongTermDebtFinancingActivities Long-Term Debt (b) |
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62 |
ProceedsFromIssuanceOfPreferredStockFinancingActivities Preferred Stock |
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63 |
ProceedsFromIssuanceOfCommonStockFinancingActivities Common Stock |
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64 |
OtherAdjustmentsToCashFlowsFromFinancingActivities Other (provide details in footnote): |
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64.1 |
OtherAdjustmentsToCashFlowsFromFinancingActivitiesDescription |
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66 |
NetIncreaseInShortTermDebt Net Increase in Short-Term Debt (c) |
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67 |
OtherAdjustmentsByOutsideSourcesToCashFlowsFromFinancingActivities Other (provide details in footnote): |
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70 |
CashProvidedByOutsideSources Cash Provided by Outside Sources (Total 61 thru 69) |
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72 |
PaymentsForRetirementAbstract Payments for Retirement of: |
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73 |
PaymentsForRetirementOfLongTermDebtFinancingActivities Long-term Debt (b) |
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74 |
PaymentsForRetirementOfPreferredStockFinancingActivities Preferred Stock |
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75 |
PaymentsForRetirementOfCommonStockFinancingActivities Common Stock |
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76 |
OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities Other (provide details in footnote): |
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|
76.1 |
DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities |
(b) |
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76.2 |
DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities |
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76.3 |
DescriptionOfOtherRetirementsImpactingCashFlowsFromFinancingActivities |
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78 |
NetDecreaseInShortTermDebt Net Decrease in Short-Term Debt (c) |
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80 |
DividendsOnPreferredStock Dividends on Preferred Stock |
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81 |
DividendsOnCommonStock Dividends on Common Stock |
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83 |
CashFlowsProvidedFromUsedInFinancingActivities Net Cash Provided by (Used in) Financing Activities (Total of lines 70 thru 81) |
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85 |
NetIncreaseDecreaseInCashAndCashEquivalentsAbstract Net Increase (Decrease) in Cash and Cash Equivalents |
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86 |
NetIncreaseDecreaseInCashAndCashEquivalents Net Increase (Decrease) in Cash and Cash Equivalents (Total of line 22, 57 and 83) |
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88 |
CashAndCashEquivalents Cash and Cash Equivalents at Beginning of Period |
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90 |
CashAndCashEquivalents Cash and Cash Equivalents at End of Period |
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Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: OtherAdjustmentsToCashFlowsFromInvestmentActivities | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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| (b) Concept: OtherRetirementsOfBalancesImpactingCashFlowsFromFinancingActivities | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
NOTES TO FINANCIAL STATEMENTS |
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A. CASH FLOW STATEMENT, ADDITIONAL INFORMATION:
B. FERC FORM 1 PRESENTATION COMPARED TO GENERALLY ACCEPTED ACCOUNTING PRINCIPLES The accompanying financial statements have been prepared in accordance with the accounting requirements of the FERC as set forth in the Uniform System of Accounts and accounting releases, which differs from GAAP. Additional comparative data, including the 2021 data for the statement of income, retained earnings and cash flows, are needed to present the financial position and results of operations in order to satisfy GAAP. In addition, GAAP requires the disclosure of the current and long-term portion of assets and liabilities. In accordance with FERC reporting requirements, the aforementioned disclosures were not included in these financial statements. As required by the FERC, Entergy Mississippi classifies certain items in the income statement (primarily the classification of operating expenses and other deductions) and in the balance sheet (primarily the classification of the components of accumulated deferred income taxes, taxes accrued, certain other miscellaneous current and accrued liabilities, maturities of long-term debt, deferred debits, deferred credits, plant in service, and accumulated depreciation) in a manner different than that required by GAAP. GAAP requires that Entergy Mississippi consolidate MS Sunflower Partnership, LLC due to the significant influence it exerts as the managing member of the partnership, whereas Entergy Mississippi's investment in the partnership is presented in the FERC Form 1 as an equity-method investment. Additionally, GAAP requires Entergy Mississippi to record the earnings it receives from the partnership using the hypothetical-liquidation at book value (HLBV) method of accounting because the limited liability agreement forming the partnership stipulates a disproportionate allocation of tax attributes, earnings, and cash flows between Entergy Mississippi and the other investor in the partnership. In contrast, Entergy Mississippi recognizes its share in the partnership earnings based on its ownership-percentage in the partnership for reporting in the FERC Form 1. C. The Notes to the Financial Statements included herein are adapted from the Entergy Corporation and subsidiaries Form 10-K for the Year Ended December 31, 2023. The Form 10-K Notes to the Financial Statements are prepared in conformity with GAAP, and thus may differ in certain instances from the financial statements contained herein. "Entergy" when used in these Notes means Entergy Corporation and its direct and indirect subsidiaries. "Registrant Subsidiaries" when used in these Notes means Entergy Arkansas, LLC, Entergy Louisiana, LLC, Entergy Mississippi, LLC, Entergy New Orleans, LLC, Entergy Texas, Inc., and System Energy Resources, Inc. "Utility" when used in the Notes means Entergy's business segment that generates, transmits, distributes, and sells electric power, with a small amount of natural gas distribution. "Utility operating companies" when used in these Notes means Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas. |
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NOTE 1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Use of Estimates in the Preparation of Financial Statements In conformity with GAAP in the United States of America, the preparation of Entergy Corporation’s consolidated financial statements and the separate financial statements of the Registrant Subsidiaries requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues, and expenses, and the disclosure of contingent assets and liabilities. Adjustments to the reported amounts of assets and liabilities may be necessary in the future to the extent that future estimates or actual results are different from the estimates used. Property, Plant, and Equipment Property, plant, and equipment is stated at original cost less regulatory disallowances and impairments. Depreciation is computed on the straight-line basis at rates based on the applicable estimated service lives of the various classes of property. For the Registrant Subsidiaries, the original cost of plant retired or removed, less salvage, is charged to accumulated depreciation. Normal maintenance, repairs, and minor replacement costs are charged to operating expenses. Certain combined-cycle gas turbine generating units are maintained under long-term service agreements with third-party service providers. The costs under these agreements are split between operating expenses and capital additions based upon the nature of the work performed. Substantially all of the Registrant Subsidiaries’ plant is subject to mortgage liens. Details of property, plant, and equipment by functional category are presented on FERC Form 1 pages 204-207 and details of accumulated depreciation by functional category are presented on FERC Form 1 page 219. Depreciation rates on average depreciable property for the Registrant Subsidiaries are shown below:
Jointly-Owned Generating Stations Certain Entergy subsidiaries jointly own electric generating facilities with affiliates or third parties. All parties are required to provide their own financing. The investments, fuel expenses, and other operation and maintenance expenses associated with these generating stations are recorded by the Entergy subsidiaries to the extent of their respective undivided ownership interests. As of December 31, 2023, the subsidiaries’ investment and accumulated depreciation in each of these generating stations were as follows:
a.“Total Megawatt Capability” is the dependable summer load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize. b.Ouachita Units 1 and 2 are owned 100% by Entergy Arkansas and Ouachita Unit 3 is owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the common facilities and not for the generating units. c.Union Unit 1 is owned 100% by Entergy New Orleans, Union Unit 2 is owned 100% by Entergy Arkansas, Union Units 3 and 4 are owned 100% by Entergy Louisiana. The investment and accumulated depreciation numbers above are only for the specified common facilities and not for the generating units. d.Includes a leasehold interest held by System Energy. Allowance for Funds Used During Construction (AFUDC) AFUDC represents the approximate net composite interest cost of borrowed funds and a reasonable return on the equity funds used for construction by the Registrant Subsidiaries. AFUDC increases both the plant balance and earnings and is realized in cash through depreciation provisions included in the rates charged to customers. Income Taxes Entergy Corporation and the majority of its subsidiaries file a United States consolidated federal income tax return. Each tax-paying entity records income taxes as if it were a separate taxpayer and consolidating adjustments are allocated to the tax filing entities in accordance with Entergy’s intercompany income tax allocation agreements. Deferred income taxes are recorded for temporary differences between the book and tax basis of assets and liabilities, and for certain losses and credits available for carryforward. Deferred tax assets are reduced by a valuation allowance when, in the opinion of management, it is more likely than not that some portion of the deferred tax assets will not be realized. Deferred tax assets and liabilities are adjusted for the effects of changes in tax laws and rates in the period in which the tax or rate was enacted. See the “Other Tax Matters - Tax Cuts and Jobs Act” section in Note 3 to the financial statements for discussion of the effects of the enactment of the Tax Cuts and Jobs Act in December 2017. The benefits of investment tax credits are deferred and amortized over the average useful life of the related property, as a reduction of income tax expense, for such credits associated with rate-regulated operations in accordance with ratemaking treatment. Accounting for the Effects of Regulation Entergy’s Utility operating companies and System Energy are rate-regulated entities that are required to reflect the effects of rate regulation in their financial statements, including the recording of regulatory assets and liabilities, as the Utility operating companies and System Energy have rates that meet the following three criteria: (1) are approved by a third-party regulator; (2) are designed to recover the entities’ cost of providing the regulated services or products; and (3) can reasonably be assumed will be charged to and collected from customers. These criteria may also be applied to separable portions of a utility’s business, such as the generation or transmission functions, or to specific classes of customers. Regulatory assets represent incurred costs that have been deferred because they are probable of future recovery from customers through regulated rates. Regulatory liabilities represent (1) revenue or gains that have been deferred because it is probable such amounts will be credited to customers through future regulated rates or (2) billings in advance of expenditures for approved regulatory programs. To the extent that all or portions of the Utility operating companies or System Energy’s operations cease to be subject to rate regulation, or future recovery or settlement is no longer probable as a result of changes in regulation or other reasons, the related regulatory assets and liabilities are eliminated from the balance sheet and the impact is recognized on the income statement. In addition, regulatory accounting requires recognition of an impairment loss if it becomes probable that part of the cost of a recently completed plant asset will be disallowed for rate-making purposes and a reasonable estimate of the amount of the disallowance can be made. Regulatory Asset or Liability for Income Taxes Accounting standards for income taxes provide that a regulatory asset or liability be recorded if it is probable that the currently determinable future increase or decrease in regulatory income tax expense will be recovered from or credited to customers through future rates. There are two main sources of Entergy’s regulatory asset or liability for income taxes. There is a regulatory asset related to the ratemaking treatment of the tax effects of book depreciation for the equity component of AFUDC that has been capitalized to property, plant, and equipment but for which there is no corresponding tax basis. Equity-AFUDC is a component of property, plant, and equipment that is included in rate base when the plant is placed in service. There is a regulatory liability related to the adjustment of Entergy’s net deferred income taxes that was required by the enactment in December 2017 of a change in the federal corporate income tax rate, which is discussed in Note 2 and 3 to the financial statements. Cash and Cash Equivalents Entergy considers all unrestricted highly liquid debt instruments with an original maturity of three months or less at date of purchase to be cash equivalents. Allowance for Doubtful Accounts The allowance for doubtful accounts reflects Entergy’s best estimate of expected losses on its accounts receivable balances. The allowance is calculated as the historical rate of customer write-offs multiplied by the current accounts receivable balance, taking into account the length of time the receivable balances have been outstanding. Although the rate of customer write-offs has historically experienced minimal variation, management monitors the current condition of individual customer accounts to manage collections and ensure bad debt expense is recorded in a timely manner. The Utility operating companies’ customer accounts receivable are written off consistent with approved regulatory requirements. Derivative Financial Instruments and Commodity Derivatives The accounting standards for derivative instruments and hedging activities require that all derivatives be recognized at fair value on the balance sheet, either as assets or liabilities, unless they meet various exceptions including the normal purchase/normal sale criteria. The changes in the fair value of recognized derivatives are recorded each period in current earnings or other comprehensive income, depending on whether a derivative is designated as part of a hedge transaction and the type of hedge transaction. Due to regulatory treatment, an offsetting regulatory asset or liability is recorded for changes in fair value of recognized derivatives for the Registrant Subsidiaries. Contracts for commodities that will be physically delivered in quantities expected to be used or sold in the ordinary course of business, including certain purchases and sales of power and fuel, meet the normal purchase, normal sales criteria and are not recognized on the balance sheet. Revenues and expenses from these contracts are reported on a gross basis in the appropriate revenue and expense categories as the commodities are received or delivered. For other contracts for commodities in which Entergy is hedging the variability of cash flows related to a variable-rate asset, liability, or forecasted transactions that qualify as cash flow hedges, the changes in the fair value of such derivative instruments are reported in other comprehensive income. To qualify for hedge accounting, the relationship between the hedging instrument and the hedged item must be documented to include the risk management objective and strategy and, at inception and on an ongoing basis, the effectiveness of the hedge in offsetting the changes in the cash flows of the item being hedged. Gains or losses accumulated in other comprehensive income are reclassified to earnings in the periods when the underlying transactions actually occur. Changes in the fair value of derivative instruments that are not designated as cash flow hedges are recorded in current-period earnings on a mark-to-market basis. Entergy has determined that contracts to purchase uranium do not meet the definition of a derivative under the accounting standards for derivative instruments because they do not provide for net settlement and the uranium markets are not sufficiently liquid to conclude that forward contracts are readily convertible to cash. If the uranium markets do become sufficiently liquid in the future and Entergy begins to account for uranium purchase contracts as derivative instruments, the fair value of these contracts would be accounted for consistent with Entergy’s other derivative instruments. See Note 15 to the financial statements for further details on Entergy’s derivative instruments and hedging activities. Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. See Note 15 to the financial statements for further discussion of fair value. Impairment of Long-lived Assets Entergy periodically reviews long-lived assets whenever events or changes in circumstances indicate that recoverability of these assets is uncertain. Generally, the determination of recoverability is based on the undiscounted net cash flows expected to result from such operations and assets. Projected net cash flows depend on the expected operating life of the assets, the future operating costs associated with the assets, the efficiency and availability of the assets and generating units, and the future market and price for energy and capacity over the remaining life of the assets. Reacquired Debt The premiums and costs associated with reacquired debt of Entergy’s Utility operating companies and System Energy (except that portion allocable to the deregulated operations of Entergy Louisiana) are included in regulatory assets and are being amortized over the life of the related new issuances, or over the life of the original debt issuance if the debt is not refinanced, in accordance with ratemaking treatment. Taxes Imposed on Revenue-Producing Transactions Governmental authorities assess taxes that are both imposed on and concurrent with a specific revenue-producing transaction between a seller and a customer, including, but not limited to, sales, use, value added, and some excise taxes. Entergy presents these taxes on a net basis, excluding them from revenues, unless required to report them differently by a regulatory authority. NOTE 2. RATE AND REGULATORY MATTERS Regulatory Assets and Regulatory Liabilities Regulatory assets represent probable future revenues associated with costs that Entergy expects to recover from customers through the regulatory ratemaking process under which the Utility business operates. Regulatory liabilities represent probable future reductions in revenues associated with amounts that Entergy expects to benefit customers through the regulatory ratemaking process under which the Utility business operates. Details of regulatory assets in FERC account 182.3 are presented on FERC Form 1 page 232. Details of regulatory liabilities in FERC account 254 are presented on FERC Form 1 page 278. Regulatory activity regarding the Tax Cuts and Jobs Act See the “Other Tax Matters - Tax Cuts and Jobs Act” section in Note 3 to the financial statements for discussion of the effects of the December 2017 enactment of the Tax Cuts and Jobs Act (Tax Act), including its effects on Entergy’s and the Registrant Subsidiaries’ regulatory asset/liability for income taxes. Fuel and purchased power cost recovery The Utility operating companies are allowed to recover fuel and purchased power costs through fuel mechanisms included in electric and gas rates that are recorded as fuel cost recovery revenues. The difference between revenues collected and the current fuel and purchased power costs is generally recorded as “Deferred fuel costs” on the Utility operating companies’ financial statements. The table below shows the amount of deferred fuel costs as of December 31, 2023 and 2022 that each Utility operating company expects to recover (or return to customers) through fuel mechanisms, subject to subsequent regulatory review.
a.Includes $68.9 million in 2022 of fuel and purchased power costs whose recovery period was indeterminate but was expected to be recovered over a period greater than twelve months. b.Includes $168.1 million in both years for Entergy Louisiana and $4.1 million in both years for Entergy New Orleans of fuel, purchased power, and capacity costs, which do not currently earn a return on investment and whose recovery periods are indeterminate but are expected to be recovered over a period greater than twelve months. Entergy Mississippi Entergy Mississippi’s rate schedules include an energy cost recovery rider and a power management rider, both of which are adjusted annually to reflect accumulated over- or under-recoveries. Entergy Mississippi recovers fuel and purchased energy costs through its energy cost recovery rider and recovers costs associated with natural gas hedging and capacity payments through its power management rider. Entergy Mississippi’s fuel cost recoveries are subject to annual audits conducted pursuant to the authority of the MPSC. In November 2020, Entergy Mississippi filed its annual redetermination of the annual factor to be applied under the energy cost recovery rider. The calculation of the annual factor included an over-recovery of approximately $24.4 million as of September 30, 2020. In January 2021 the MPSC approved the proposed energy cost factor effective for February 2021 bills. In November 2021, Entergy Mississippi filed its annual redetermination of the annual factor to be applied under the energy cost recovery rider. The calculation of the annual factor included an under-recovery of approximately $80.6 million as of September 30, 2021. In December 2021, at the request of the MPSC, Entergy Mississippi submitted a proposal to mitigate the impact of rising fuel costs on customer bills during 2022. Entergy Mississippi proposed that the deferred fuel balance as of December 31, 2021, which was $121.9 million, be amortized over three years and that the MPSC authorize Entergy Mississippi to apply its weighted-average cost of capital as the carrying cost for the unamortized fuel balance. In January 2022 the MPSC approved the amortization of $100 million of the deferred fuel balance over two years and authorized Entergy Mississippi to apply its weighted-average cost of capital as the carrying cost for the unamortized fuel balance. The MPSC approved the proposed energy cost factor effective for February 2022 bills. See “Complaints Against System Energy - System Energy Settlement with the MPSC” below for discussion of the settlement agreement filed with the FERC in June 2022. The settlement, which was approved by the FERC in November 2022, provided for a refund of $235 million from System Energy to Entergy Mississippi. In July 2022 the MPSC directed the disbursement of settlement proceeds, ordering Entergy Mississippi to provide a one-time $80 bill credit to each of its approximately 460,000 retail customers to be effective during the September 2022 billing cycle and to apply the remaining proceeds to Entergy Mississippi’s under-recovered deferred fuel balance. In accordance with the MPSC’s directive, Entergy Mississippi provided approximately $36.7 million in customer bill credits as a result of the settlement. In November 2022, Entergy Mississippi applied the remaining settlement proceeds in the amount of approximately $198.3 million to Entergy Mississippi’s under-recovered deferred fuel balance. Entergy Mississippi had a deferred fuel balance of approximately $291.7 million under the energy cost recovery rider as of July 31, 2022, along with an over-recovery balance of $51.1 million under the power management rider. Without further action, Entergy Mississippi anticipated a year-end deferred fuel balance of approximately $200 million after application of a portion of the System Energy settlement proceeds, as discussed above. In September 2022, Entergy Mississippi filed for interim adjustments under both the energy cost recovery rider and the power management rider. Entergy Mississippi proposed five monthly incremental adjustments to the net energy cost factor designed to collect the under-recovered fuel balance as of July 31, 2022 and to reflect the recovery of a higher natural gas price. Entergy Mississippi also proposed five monthly incremental adjustments to the power management adjustment factor designed to flow through to customers the over-recovered power management rider balance as of July 31, 2022. In October 2022 the MPSC approved modified interim adjustments to Entergy Mississippi’s energy cost recovery rider and power management rider. The MPSC approved dividing the energy cost recovery rider interim adjustment into two components that would allow Entergy Mississippi to (1) recover a natural gas fuel rate that is better aligned with current prices; and (2) recover the estimated under-recovered deferred fuel balance as of September 30, 2022 over a period of 20 months. The MPSC approved six monthly incremental adjustments to the net energy cost factor designed to reflect the recovery of a higher natural gas price. The MPSC also approved six monthly incremental adjustments to the power management adjustment factor designed to flow through to customers the over-recovered power management rider balance. In accordance with the order of the MPSC, Entergy Mississippi did not file an annual redetermination of the energy cost recovery rider or the power management rider in November 2022. In June 2023 the MPSC approved the joint stipulation agreement between Entergy Mississippi and the Mississippi Public Utilities Staff for Entergy Mississippi’s 2023 formula rate plan filing. The stipulation directed Entergy Mississippi to make a compliance filing to revise its power management cost adjustment factor, to revise its grid modernization cost adjustment factor, and to include a revision to reduce the net energy cost factor to a level necessary to reflect an average natural gas price of $4.50 per MMBtu. The MPSC approved the compliance filing in June 2023, effective for July 2023 bills. See “Retail Rate Proceedings - Filings with the MPSC (Entergy Mississippi) - Retail Rates - 2023 Formula Rate Plan Filing” below for further discussion of the 2023 formula rate plan filing and the joint stipulation agreement. In November 2023 Entergy Mississippi filed its annual redeterminations of the energy cost factor and the power management cost adjustment factor. The calculation of the annual factor for the energy cost recovery rider included a projected over-recovery balance of approximately $142 million at the end of January 2024. The calculation of the annual factor for the power management rider included a projected under-recovery of $47 million at the end of January 2024. In January 2024 the MPSC approved the proposed energy cost factor and the proposed power management cost factor effective for February 2024 bills. Retail Rate Proceedings Filings with the MPSC (Entergy Mississippi) Retail Rates 2021 Formula Rate Plan Filing In March 2021, Entergy Mississippi submitted its formula rate plan 2021 test year filing and 2020 look-back filing showing Entergy Mississippi’s earned return for the historical 2020 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2021 calendar year to be below the formula rate plan bandwidth. The 2021 test year filing showed a $95.4 million rate increase was necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.69% return on rate base, within the formula rate plan bandwidth. The change in formula rate plan revenues, however, was capped at 4% of retail revenues, which equated to a revenue change of $44.3 million. The 2021 evaluation report also included $3.9 million in demand side management costs for which the MPSC approved realignment of recovery from the energy efficiency rider to the formula rate plan. These costs were not subject to the 4% cap and resulted in a total change in formula rate plan revenues of $48.2 million. The 2020 look-back filing compared actual 2020 results to the approved benchmark return on rate base and reflected the need for a $16.8 million interim increase in formula rate plan revenues. In addition, the 2020 look-back filing included an interim capacity adjustment true-up for the Choctaw Generating Station, which increased the look-back interim rate adjustment by $1.7 million. These interim rate adjustments totaled $18.5 million. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $22.1 million interim rate increase, reflecting a cap equal to 2% of 2020 retail revenues, effective with the April 2021 billing cycle, subject to refund, pending a final MPSC order. The $3.9 million of demand side management costs and the Choctaw Generating Station true-up of $1.7 million, which were not subject to the 2% cap of 2020 retail revenues, were included in the April 2021 rate adjustments. In June 2021, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed the 2021 test year filing that resulted in a total rate increase of $48.2 million. Pursuant to the joint stipulation, Entergy Mississippi’s 2020 look-back filing reflected an earned return on rate base of 6.12% in calendar year 2020, which was below the look-back bandwidth, resulting in a $17.5 million increase in formula rate plan revenues on an interim basis through June 2022. This included $1.7 million related to the Choctaw Generating Station and $3.7 million of COVID-19 non-bad debt expenses. The joint stipulation also included Entergy Mississippi’s quantification and methodology for calculating incremental COVID-19 bad debt expenses and provided for Entergy Mississippi to continue to defer these incremental COVID-19 bad debt expenses through December 2021. In June 2021 the MPSC approved the joint stipulation with rates effective for the first billing cycle of July 2021. In June 2021, Entergy Mississippi recorded regulatory credits of $19.9 million to reflect the effects of the joint stipulation. 2022 Formula Rate Plan Filing In March 2022, Entergy Mississippi submitted its formula rate plan 2022 test year filing and 2021 look-back filing showing Entergy Mississippi’s earned return for the historical 2021 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2022 calendar year to be below the formula rate plan bandwidth. The 2022 test year filing showed a $69 million rate increase was necessary to reset Entergy Mississippi’s earned return on common equity to the specified point of adjustment of 6.70% return on rate base, within the formula rate plan bandwidth. The change in formula rate plan revenues, however, was capped at 4% of retail revenues, which equated to a revenue change of $48.6 million. The 2021 look-back filing compared actual 2021 results to the approved benchmark return on rate base and reflected the need for a $34.5 million interim increase in formula rate plan revenues. In fourth quarter 2021, Entergy Mississippi recorded a regulatory asset of $19 million to reflect the then-current estimate in connection with the look-back feature of the formula rate plan. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $24.3 million interim rate increase, reflecting a cap equal to 2% of 2021 retail revenues, effective in April 2022. With the implementation of the interim formula rate plan rates, Entergy Mississippi began recovery of the bad debt expense deferral resulting from the COVID-19 pandemic over a three-year period. In June 2022, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed the 2022 test year filing that resulted in a total rate increase of $48.6 million. Pursuant to the joint stipulation, Entergy Mississippi’s 2021 look-back filing reflected an earned return on rate base of 5.99% in calendar year 2021, which was below the look-back bandwidth, resulting in a $34.3 million increase in the formula rate plan revenues on an interim basis through June 2023. In July 2022 the MPSC approved the joint stipulation with rates effective in August 2022. In July 2022, Entergy Mississippi recorded regulatory credits of $22.6 million to reflect the effects of the joint stipulation. In August 2022 an intervenor filed a statutorily-authorized direct appeal to the Mississippi Supreme Court seeking review of the MPSC’s July 2022 order approving the joint stipulation confirming Entergy Mississippi’s 2022 formula rate plan filing. Formula rate plan rates are not stayed or otherwise impacted while the appeal is pending. In July 2022 the MPSC directed Entergy Mississippi to flow $14.1 million of the power management rider over-recovery balance to customers beginning in August 2022 through December 2022 to mitigate the bill impact of the increase in formula rate plan revenues. 2023 Formula Rate Plan Filing In March 2023, Entergy Mississippi submitted its formula rate plan 2023 test year filing and 2022 look-back filing showing Entergy Mississippi’s earned return on rate base for the historical 2022 calendar year to be below the formula rate plan bandwidth and projected earned return for the 2023 calendar year to be below the formula rate plan bandwidth. The 2023 test year filing showed a $39.8 million rate increase was necessary to reset Entergy Mississippi’s earned return on rate base to the specified point of adjustment of 6.67%, within the formula rate plan bandwidth. The 2022 look-back filing compared actual 2022 results to the approved benchmark return on rate base and reflected the need for a $19.8 million temporary increase in formula rate plan revenues, including the refund of a $1.3 million over-recovery resulting from the demand-side management costs true-up for 2022. In fourth quarter 2022, Entergy Mississippi recorded a regulatory asset of $18.2 million in connection with the look-back feature of the formula rate plan to reflect that the 2022 estimated earned return was below the formula rate plan bandwidth. In accordance with the provisions of the formula rate plan, Entergy Mississippi implemented a $27.9 million interim rate increase, reflecting a cap equal to 2% of 2022 retail revenues, effective in April 2023. In May 2023, Entergy Mississippi and the Mississippi Public Utilities Staff entered into a joint stipulation that confirmed a 2023 test year filing resulting in a total revenue increase of $26.5 million for 2023. Pursuant to the joint stipulation, Entergy Mississippi’s 2022 look-back filing reflected an earned return on rate base of 6.10% in calendar year 2022, which was below the look-back bandwidth, resulting in a $19.0 million increase in the formula rate plan revenues on an interim basis through June 2024. Entergy Mississippi recorded a regulatory credit of $0.8 million in June 2023 to reflect the increase in the look-back regulatory asset. In addition, certain long-term service agreement and conductor handling costs were authorized for realignment from the formula rate plan to the annual power management and grid modernization riders effective January 2023, resulting in regulatory credits recorded in June 2023 of $4.1 million and $4.3 million, respectively. Also, the amortization of Entergy Mississippi’s COVID-19 bad debt expense deferral was suspended for calendar year 2023 and will resume in 2024. In June 2023 the MPSC approved the joint stipulation with rates effective in July 2023. Entergy Arkansas Opportunity Sales Proceeding In June 2009 the LPSC filed a complaint requesting that the FERC determine that certain of Entergy Arkansas’s sales of electric energy to third parties: (a) violated the provisions of the System Agreement that allocated the energy generated by Entergy System resources; (b) imprudently denied the Entergy System and its ultimate consumers the benefits of low-cost Entergy System generating capacity; and (c) violated the provision of the System Agreement that prohibited sales to third parties by individual companies absent an offer of a right-of-first-refusal to other Utility operating companies. The LPSC’s complaint challenged sales made beginning in 2002 and requested refunds. In July 2009 the Utility operating companies filed a response to the complaint arguing among other things that the System Agreement contemplates that the Utility operating companies may make sales to third parties for their own account, subject to the requirement that those sales be included in the load (or load shape) for the applicable Utility operating company. The FERC subsequently ordered a hearing in the proceeding. After a hearing, the ALJ issued an initial decision in December 2010. The ALJ found that the System Agreement allowed for Entergy Arkansas to make the sales to third parties but concluded that the sales should be accounted for in the same manner as joint account sales. The ALJ concluded that “shareholders” should make refunds of the damages to the Utility operating companies, along with interest. Entergy disagreed with several aspects of the ALJ’s initial decision and in January 2011 filed with the FERC exceptions to the decision. The FERC issued a decision in June 2012 and held that, while the System Agreement is ambiguous, it does provide authority for individual Utility operating companies to make opportunity sales for their own account and Entergy Arkansas made and priced these sales in good faith. The FERC found, however, that the System Agreement does not provide authority for an individual Utility operating company to allocate the energy associated with such opportunity sales as part of its load but provides a different allocation authority. The FERC further found that the after-the-fact accounting methodology used to allocate the energy used to supply the sales was inconsistent with the System Agreement. The FERC in its decision established further hearing procedures to quantify the effect of repricing the opportunity sales in accordance with the FERC’s June 2012 decision. The hearing was held in May 2013 and the ALJ issued an initial decision in August 2013. The LPSC, the APSC, the City Council, and FERC staff filed briefs on exceptions and/or briefs opposing exceptions. Entergy filed a brief on exceptions requesting that the FERC reverse the initial decision and a brief opposing certain exceptions taken by the LPSC and FERC staff. In April 2016 the FERC issued orders addressing requests for rehearing filed in July 2012 and the ALJ’s August 2013 initial decision. The first order denied Entergy’s request for rehearing and affirmed the FERC’s earlier rulings that Entergy’s original methodology for allocating energy costs to the opportunity sales was incorrect and, as a result, Entergy Arkansas must make payments to the other Utility operating companies to put them in the same position that they would have been in absent the incorrect allocation. The FERC clarified that interest should be included with the payments. The second order affirmed in part, and reversed in part, the rulings in the ALJ’s August 2013 initial decision regarding the methodology that should be used to calculate the payments Entergy Arkansas is to make to the other Utility operating companies. The FERC affirmed the ALJ’s ruling that a full re-run of intra-system bills should be performed but required that methodology be modified so that the sales have the same priority for purposes of energy allocation as joint account sales. The FERC reversed the ALJ’s decision that any payments by Entergy Arkansas should be reduced by 20%. The FERC also reversed the ALJ’s decision that adjustments to other System Agreement service schedules and excess bandwidth payments should not be taken into account when calculating the payments to be made by Entergy Arkansas. The FERC held that such adjustments and excess bandwidth payments should be taken into account but ordered further proceedings before an ALJ to address whether a cap on any reduction due to bandwidth payments was necessary and to implement the other adjustments to the calculation methodology. In May 2016, Entergy Services filed a request for rehearing of the FERC’s April 2016 order arguing that payments made by Entergy Arkansas should be reduced as a result of the timing of the LPSC’s approval of certain contracts. Entergy Services also filed a request for clarification and/or rehearing of the FERC’s April 2016 order addressing the ALJ’s August 2013 initial decision. The APSC and the LPSC also filed requests for rehearing of the FERC’s April 2016 order. In September 2017 the FERC issued an order denying the request for rehearing on the issue of whether any payments by Entergy Arkansas to the other Utility operating companies should be reduced due to the timing of the LPSC’s approval of Entergy Arkansas’s wholesale baseload contract with Entergy Louisiana. In November 2017 the FERC issued an order denying all of the remaining requests for rehearing of the April 2016 order. In November 2017, Entergy Services filed a petition for review in the D.C. Circuit of the FERC’s orders in the first two phases of the opportunity sales case. In December 2017 the D.C. Circuit granted Entergy Services’ request to hold the appeal in abeyance pending final resolution of the related proceeding before the FERC. In January 2018 the APSC and the LPSC filed separate petitions for review in the D.C. Circuit, and the D.C. Circuit consolidated the appeals with Entergy Services’ appeal. The hearing required by the FERC’s April 2016 order was held in May 2017. In July 2017 the ALJ issued an initial decision addressing whether a cap on any reduction due to bandwidth payments was necessary and whether to implement the other adjustments to the calculation methodology. In August 2017 the Utility operating companies, the LPSC, the APSC, and FERC staff filed individual briefs on exceptions challenging various aspects of the initial decision. In September 2017 the Utility operating companies, the LPSC, the APSC, the MPSC, the City Council, and FERC staff filed separate briefs opposing exceptions taken by various parties. Based on testimony previously submitted in the case and its assessment of the April 2016 FERC orders, in the first quarter 2016, Entergy Arkansas recorded a liability of $87 million, which included interest, for its estimated increased costs and payment to the other Utility operating companies, and a deferred fuel regulatory asset of $75 million. Following its assessment of the course of the proceedings, including the FERC’s denial of rehearing in November 2017 described above, in the fourth quarter 2017, Entergy Arkansas recorded an additional liability of $35 million and a regulatory asset of $31 million. In October 2018 the FERC issued an order addressing the ALJ’s July 2017 initial decision. The FERC reversed the ALJ’s decision to cap the reduction in Entergy Arkansas’s payment to account for the increased bandwidth payments that Entergy Arkansas made to the other operating companies. The FERC also reversed the ALJ’s decision that Grand Gulf sales from January through September 2000 should be included in the calculation of Entergy Arkansas’s payment. The FERC affirmed on other grounds the ALJ’s rejection of the LPSC’s claim that certain joint account sales should be accounted for as part of the calculation of Entergy Arkansas’s payment. In November 2018 the LPSC requested rehearing of the FERC’s October 2018 decision. In December 2019 the FERC denied the LPSC’s request for rehearing. In January 2020 the LPSC appealed the December 2019 decision to the D.C. Circuit. In December 2018, Entergy made a compliance filing in response to the FERC’s October 2018 order. The compliance filing provided a final calculation of Entergy Arkansas’s payments to the other Utility operating companies, including interest. No protests were filed in response to the December 2018 compliance filing. Refunds and interest in the following amounts were paid by Entergy Arkansas to the other operating companies in December 2018:
As described above, the FERC’s opportunity sales orders were appealed to the D.C. Circuit. In February 2020 all of the appeals were consolidated and in April 2020 the D.C. Circuit established a briefing schedule. Briefing was completed in September 2020 and oral argument was heard in December 2020. In July 2021 the D.C. Circuit issued a decision denying all of the petitions for review filed in response to the FERC’s opportunity sales orders. System Energy Settlement with the MPSC In June 2022, System Energy, Entergy Mississippi, and additional named Entergy parties involved in thirteen docketed proceedings before the FERC filed with the FERC a partial settlement agreement and offer of settlement. The settlement memorializes the Entergy parties’ agreement with the MPSC to globally resolve all actual and potential claims between the Entergy parties and the MPSC associated with those FERC proceedings and with System Energy’s past implementation of the Unit Power Sales Agreement. The Unit Power Sales Agreement is a FERC-jurisdictional formula rate tariff for sales of energy and capacity from System Energy’s owned and leased share of Grand Gulf to Entergy Mississippi, Entergy Arkansas, Entergy Louisiana, and Entergy New Orleans. Entergy Mississippi purchases the greatest single amount, nearly 40% of System Energy’s share of Grand Gulf, after its additional purchases from affiliates are considered. The settlement therefore limits System Energy’s overall refund exposure associated with the identified proceedings because they will be resolved completely as between the Entergy parties and the MPSC. The settlement provided for a black-box refund of $235 million from System Energy to Entergy Mississippi, which was to be paid within 120 days of the settlement’s effective date (either the date of the FERC approval of the settlement without material modification, or the date that all settling parties agree to accept modifications or otherwise modify the settlement in response to a proposed material modification by the FERC). In addition, beginning with the July 2022 service month, the settlement provided for Entergy Mississippi’s bills from System Energy to be adjusted to reflect: an authorized rate of return on equity of 9.65%, a capital structure not to exceed 52% equity, a rate base reduction for the advance collection of sale-leaseback rental costs, and the exclusion of certain long-term incentive plan performance unit costs from rates. The settlement was approved by the MPSC in June 2022 and the FERC in November 2022. System Energy previously recorded a provision and associated liability of $37 million for elements of the applicable litigation. In June 2022, System Energy recorded a regulatory charge of $551 million ($413 million net-of-tax), increasing the regulatory liability to $588 million, which consisted of $235 million for the settlement with the MPSC and $353 million for potential future refunds to Entergy Arkansas, Entergy Louisiana, and Entergy New Orleans. System Energy paid the black-box refund of $235 million to Entergy Mississippi in November 2022. See “System Energy Regulatory Liability for Pending Complaints” below for discussion of the regulatory liability related to complaints against System Energy as of December 31, 2023. Storm Cost Recovery Filings with Retail Regulators Entergy Mississippi Entergy Mississippi has approval from the MPSC to collect a storm damage provision of $1.75 million per month. If Entergy Mississippi’s accumulated storm damage provision balance exceeds $15 million, the collection of the storm damage provision ceases until such time that the accumulated storm damage provision becomes less than $10 million. Entergy Mississippi’s storm damage provision balance has been less than $10 million since May 2019, and Entergy Mississippi has been billing the monthly storm damage provision since July 2019. In December 2023 Entergy Mississippi filed a Notice of Storm Escrow Disbursement and Request for Interim Relief notifying the MPSC that Entergy Mississippi had requested disbursement of approximately $34.5 million of storm escrow funds from its restricted storm escrow account. The filing also requested authorization from the MPSC, on a temporary basis, that the $34.5 million of storm escrow funds be credited to Entergy Mississippi’s storm damage provision, pending the MPSC’s review of Entergy Mississippi’s storm-related costs, and that Entergy Mississippi continue to bill its monthly storm damage provision without suspension in the event the storm damage provision balance exceeds $15 million, in anticipation of a subsequent filing by Entergy Mississippi in this proceeding. The storm damage reserve exceeded $15 million upon receipt of the storm escrow funds. Because the MPSC had not entered an order on Entergy Mississippi’s filing on the requested relief to continue billing this provision, Entergy Mississippi suspended billing the monthly storm damage provision effective with February 2024 bills. NOTE 3. INCOME TAXES Details regarding income taxes are presented on FERC Form 1 pages 261-267 and 272-277. The Registrant Subsidiaries’ estimated tax attributes carryovers and their expiration dates as of December 31, 2023 are as follows:
Unrecognized tax benefits Accounting standards establish a “more-likely-than-not” recognition threshold that must be met before a tax benefit can be recognized in the financial statements. If a tax deduction is taken on a tax return but does not meet the more-likely-than-not recognition threshold, an increase in income tax liability, above what is payable on the tax return, is required to be recorded. A reconciliation of the Registrant Subsidiaries’ beginning and ending amount of unrecognized tax benefits for 2023, 2022, and 2021 is as follows:
a.The primary additions for Entergy Louisiana in 2022 and 2023 are related to the Entergy Louisiana securitizations. b.Amounts in 2023 are primarily related to the resolution of the 2016-2018 IRS audit as discussed in “Income Tax Audits - 2016-2018 IRS Audit” below. The Registrant Subsidiaries’ balances of unrecognized tax benefits included amounts which, if recognized, would have reduced income tax expense as follows:
Accrued balances for the possible payment of interest related to unrecognized tax benefits for the Registrant Subsidiaries are as follows:
The Registrant Subsidiaries record interest and penalties related to unrecognized tax benefits in income tax expense. No penalties were recorded in 2023, 2022, and 2021. Interest (net-of-tax) was recorded as follows:
Income Tax Audits Entergy and its subsidiaries file U.S. federal and various state income tax returns. IRS examinations are complete for years before 2019. All state taxing authorities’ examinations are complete for years before 2014. Entergy regularly defends its positions and works with the IRS to resolve audits. The resolution of audit issues could result in significant changes to the amounts of unrecognized tax benefits in the next twelve months. 2016-2018 IRS Audit The IRS completed its examination of the 2016 through 2018 tax years and issued a Revenue Agent Report (RAR) for each federal filer under audit in November 2023. Entergy agreed to all adjustments contained in the RARs. Entergy and the Registrant Subsidiaries recorded all the material effects resulting from the RARs in the fourth quarter of 2023. Mark-to-Market Method of Accounting In 2018, Entergy Arkansas and Entergy Mississippi each accrued approximately $2 billion in deductible temporary differences related to mark-to-market tax accounting for the Unit Power Sales Agreement and various wholesale electric contracts. The IRS allowed the mark-to-market tax method of accounting associated with various intercompany and third-party wholesale electric contracts. The IRS disallowed the net deductions associated with the Unit Power Sales Agreement, which did not have an effect on net tax expense. The effective settlement of the mark-to-market tax position for Entergy Arkansas resulted in the accrual of an increase to tax expense of $40 million, which was offset by approximately $5 million of miscellaneous excess ADIT recognized as a result of the 2016-2018 IRS audit resolution. The net increase to tax expense is deferred as a regulatory asset, as discussed within the “Regulatory and Other Matters” section below. Reduction of Net Operating Loss Carryovers The IRS audit reduced Entergy’s net operating loss carryover by $8 billion. A portion of Entergy’s audit adjustments were not offset by losses which resulted in a tax liability of $79 million, which was fully offset by prior deposits made by Entergy. Entergy received an assessment of interest in excess of prior deposits of $13 million in December 2023, and such interest was paid in January 2024. Net operating loss carryovers were reduced by $4 billion for Entergy Arkansas, $1 billion for Entergy Louisiana, $2 billion for Entergy Mississippi, $1 billion for Entergy New Orleans, and $40 million for System Energy. The IRS audit adjustments were also factored into the settle-up required under Entergy’s intercompany income tax allocation agreement, and such amounts were settled in the fourth quarter of 2023. Regulatory and Other Matters Reversal of net deferred credits associated with the accounting for income taxes upon the resolution of the IRS audit resulted in a reduction/(increase) of income tax expense of $9 million, $42 million, ($2) million, $2 million, $2 million, and $1 million for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy, respectively. Included in the effect of the IRS audit on the results of operations was the measurement of deferred tax assets and liabilities influenced by the 2017 enactment of the Tax Cuts and Jobs Act income tax rate change discussed below. With the conclusion of the audit, there are no remaining federal unrecognized tax benefits affected by the rate differential which could impact income tax expense and the regulatory liability for income taxes in future periods. Other Tax Matters Tax Cuts and Jobs Act (TCJA) The most significant effect of the TCJA for Entergy and the Registrant Subsidiaries was the change in the federal corporate income tax rate from 35% to 21%, effective January 1, 2018. Entergy had remaining regulatory liabilities of $1.0 billion and $1.3 billion as of December 31, 2023 and December 31, 2022, respectively, mainly associated with the re-measurement of deferred tax assets and liabilities from the income tax rate change, subsequent amortization of excess ADIT, and payments to customers since the enactment of the TCJA. In addition to the protected and unprotected excess ADIT amounts, the net regulatory liability for income taxes includes other regulatory assets and liabilities for income taxes mainly for AFUDC, which is described in Note 1 to the financial statements. Entergy’s regulatory liability for income taxes includes a gross-up at the applicable tax rate because of the effect that excess ADIT has on the ratemaking formula. The regulatory liability for income taxes includes the effect of (1) the reduction of the net deferred tax liability resulting in excess ADIT, and (2) the tax gross-up of excess ADIT. The Registrant Subsidiaries’ December 31, 2023 and December 31, 2022 balance sheets reflect net regulatory liabilities for income taxes as follows:
Excess ADIT is generally classified into two categories: (1) the portion that is subject to the normalization requirements of the TCJA, referred to as “protected”, and (2) the portion that is not subject to such normalization provisions, referred to as “unprotected”. See Note 2 to the financial statements for discussion of Entergy Louisiana’s $106 million reversal of a regulatory liability, associated with the Hurricane Isaac securitization, recognized in 2017 as a result of the TCJA, recorded in fourth quarter 2023. The majority of the remaining unamortized Excess ADIT as of December 31, 2023 is classified as protected. The TCJA provides that the normalization method of accounting for income taxes is required for excess ADIT associated with public utility property. The TCJA provides for the use of the average rate assumption method (ARAM) for the determination of the timing of the return of excess ADIT associated with such property. Under ARAM, the excess ADIT is reduced over the remaining life of the asset. Remaining asset lives vary for each Registrant Subsidiary, but the average life of public utility property is typically 30 years or longer. Entergy will amortize the protected portion of the excess ADIT in conformity with the normalization requirements. During the second quarter 2018, the Registrant Subsidiaries began returning unprotected excess accumulated deferred income taxes, associated with the effects of the TCJA, to their customers through rate riders and other means approved by their respective regulatory authorities. Return of the unprotected excess accumulated deferred income taxes results in a reduction in the regulatory liability for income taxes and a corresponding reduction in income tax expense. This manner of regulatory accounting affects the effective tax rate for the period as compared to the statutory tax rate. There was no return of unprotected excess accumulated deferred income taxes for Entergy or the Registrant Subsidiaries for the year ended December 31, 2023. For the year ended December 31, 2022, the return of unprotected excess accumulated deferred income taxes reduced the regulatory liability for income taxes by $53 million for Entergy, including $25 million for Entergy Louisiana, $1 million for Entergy New Orleans, and $27 million for Entergy Texas. Inflation Reduction Act of 2022 The Inflation Reduction Act of 2022, signed into law on August 16, 2022, significantly expanded federal tax incentives for clean energy production, including the extension of production tax credits to solar projects and certain qualified nuclear power plants. Additionally, the Inflation Reduction Act of 2022 enacted a 1% excise tax on the buyback of public company stock and a new corporate alternative minimum tax. There are no effects on the financial statements of Entergy or the Registrant Subsidiaries as of and for the years ended December 31, 2023 and 2022 related to the enactment of the law. Tax Accounting Methods Certain Entergy subsidiaries have elected to apply the mark-to-market method of accounting for income tax return purposes to wholesale power purchase agreements as appropriate under the Internal Revenue Code and U.S. Treasury Regulations. The mark-to-market tax gain or loss computed each year is based on an estimated fair market valuation which includes analyses of market prices and conditions. NOTE 4. REVOLVING CREDIT FACILITIES, LINES OF CREDIT, AND SHORT-TERM BORROWINGS Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each had credit facilities available as of December 31, 2023 as follows:
a.The interest rate is the estimated interest rate as of December 31, 2023 that would have been applied to outstanding borrowings under the facility. b.Borrowings under this Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. c.The credit facility includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas. The commitment fees on the credit facilities range from 0.075% to 0.375% of the undrawn commitment amount for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas, and of the entire facility amount for Entergy New Orleans. Each of the credit facilities requires the Registrant Subsidiary borrower to maintain a debt ratio, as defined, of 65% or less of its total capitalization. Each Registrant Subsidiary is in compliance with this covenant. In addition, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas each has an uncommitted standby letter of credit facility as a means to post collateral to support its obligations to MISO and for other purposes. The following is a summary of the uncommitted standby letter of credit facilities as of December 31, 2023:
a.As of December 31, 2023, letters of credit posted with MISO covered financial transmission rights exposure of $1.2 million for Entergy Arkansas, $0.5 million for Entergy Louisiana, $0.3 million for Entergy Mississippi, and $0.1 million for Entergy Texas. See Note 15 to the financial statements for discussion of financial transmission rights. b.As of December 31, 2023, in addition to the $20 million MISO letters of credit, Entergy Mississippi had $1 million in a non-MISO letter of credit outstanding under this facility. The short-term borrowings of the Registrant Subsidiaries are limited to amounts authorized by the FERC. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas have FERC-authorized short-term borrowing limits effective through April 2025. In addition to borrowings from commercial banks, these companies may also borrow from the Entergy system money pool and from other internal short-term borrowing arrangements. The money pool is an intercompany cash management program that makes possible intercompany borrowing and lending arrangements, and the money pool and the other internal borrowing arrangements are designed to reduce the Registrant Subsidiaries’ dependence on external short-term borrowings. Borrowings from internal and external short-term borrowings combined may not exceed the FERC-authorized limits. The following are the FERC-authorized limits for short-term borrowings and the outstanding short-term borrowings as of December 31, 2023 (aggregating both internal and external short-term borrowings) for the Registrant Subsidiaries:
NOTE 5. LONG - TERM DEBT Details of long-term debt are presented on FERC Form 1 pages 256-257. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas have obtained long-term financing authorizations from the FERC that extend through April 2025. NOTE 6. PREFERRED EQUITY AND NONCONTROLLING INTERESTS Note 6 to the financial statements is not applicable to Entergy Mississippi. NOTE 7. COMMON EQUITY Note 7 to the financial statements is not applicable to Entergy Mississippi. NOTE 8. COMMITMENTS AND CONTINGENCIES Entergy and the Registrant Subsidiaries are involved in a number of legal, regulatory, and tax proceedings before various courts, regulatory authorities, and governmental agencies in the ordinary course of business. While management is unable to predict with certainty the outcome of such proceedings, management does not believe that the ultimate resolution of these matters will have a material adverse effect on Entergy’s results of operations, cash flows, or financial condition. Entergy discusses regulatory proceedings in Note 2 to the financial statements and discusses tax proceedings in Note 3 to the financial statements. Non-Nuclear Property Insurance Entergy’s non-nuclear property insurance program provides coverage on a system-wide basis for Entergy’s non-nuclear assets. The insurance program provides coverage for property damage up to $400 million per occurrence in excess of a $20 million self-insured retention except for property damage caused by the following: earthquake shock, flood, and named windstorm, including associated storm surge. For earthquake shock and flood, the insurance program provides coverage up to $400 million on an annual aggregate basis in excess of a $40 million self-insured retention. For named windstorm and associated storm surge, the insurance program provides coverage up to $125 million on an annual aggregate basis in excess of a $40 million self-insured retention. The coverage provided by the insurance program for the Entergy New Orleans gas distribution system is limited to $50 million per occurrence and is subject to the same annual aggregate limits and retentions listed above for earthquake shock, flood, and named windstorm, including associated storm surge. Covered property generally includes power plants, substations, facilities, inventories, and gas distribution-related properties. Excluded property generally includes transmission and distribution lines, poles, and towers. For substations valued at $5 million or less, coverage for named windstorm and associated storm surge is excluded. This coverage is in place for Entergy Corporation, the Registrant Subsidiaries, and certain other Entergy subsidiaries. Entergy also purchases $400 million in terrorism insurance coverage for its conventional property. Employment and Labor-related Proceedings The Registrant Subsidiaries and other Entergy subsidiaries and related entities are responding to various lawsuits in both state and federal courts and to other labor-related proceedings filed by current and former employees, recognized bargaining representatives, and certain third parties. Generally, the amount of damages being sought is not specified in these proceedings. These actions may include, but are not limited to, allegations of wrongful employment actions; wage disputes and other claims under the Fair Labor Standards Act or its state counterparts; claims of race, gender, age, and disability discrimination; disputes arising under collective bargaining agreements; unfair labor practice proceedings and other administrative proceedings before the National Labor Relations Board or concerning the National Labor Relations Act; claims of retaliation; claims of harassment and hostile work environment; and claims for or regarding benefits under various Entergy Corporation-sponsored employee benefit plans. Entergy and the Registrant Subsidiaries and related entities are responding to these lawsuits and proceedings and deny liability to the claimants. Management believes that loss exposure has been and will continue to be handled so that the ultimate resolution of these matters will not be material, in the aggregate, to the financial position, results of operation, or cash flows of Entergy or the Registrant Subsidiaries. Grand Gulf - Related Agreements Unit Power Sales Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy) System Energy has agreed to sell all of its share of capacity and energy from Grand Gulf to Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans in accordance with specified percentages (Entergy Arkansas - 36%, Entergy Louisiana - 14%, Entergy Mississippi - 33%, and Entergy New Orleans - 17%) as ordered by the FERC. Charges under this agreement are paid in consideration for the purchasing companies’ respective entitlement to receive capacity and energy and are payable irrespective of the quantity of energy delivered. In December 2016 the NRC granted the extension of Grand Gulf’s operating license to 2044. Monthly obligations are based on actual capacity and energy costs. The average monthly payments for 2023 under the agreement were approximately $17.9 million for Entergy Arkansas, $6.7 million for Entergy Louisiana, $16.3 million for Entergy Mississippi, and $8.1 million for Entergy New Orleans. See Note 2 to the financial statements for discussion of the complaints filed with the FERC against System Energy seeking a reduction in the return on equity component of the Unit Power Sales Agreement and other complaints filed with the FERC regarding the rates charged by System Energy under the System Agreement. Availability Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy) Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans are individually obligated to make payments or subordinated advances to System Energy in accordance with stated percentages (Entergy Arkansas - 17.1%, Entergy Louisiana - 26.9%, Entergy Mississippi - 31.3%, and Entergy New Orleans - 24.7%) in amounts that, when added to amounts received under the Unit Power Sales Agreement or otherwise, are adequate to cover all of System Energy’s operating expenses as defined, including expenses incurred in connection with a permanent shutdown of Grand Gulf. System Energy has assigned its rights to payments and advances to certain creditors as security for certain of its debt obligations. Since commercial operation of Grand Gulf began, payments under the Unit Power Sales Agreement to System Energy have exceeded the amounts payable under the Availability Agreement and, therefore, no payments under the Availability Agreement have ever been required. However, if Entergy Arkansas or Entergy Mississippi fails to make its Unit Power Sales Agreement payments, and System Energy is unable to obtain funds from other sources, Entergy Louisiana and Entergy New Orleans could become subject to claims or demands by System Energy or certain of its creditors for payments or advances under the Availability Agreement (or the assignments thereof) equal to the difference between their required Unit Power Sales Agreement payments and their required Availability Agreement payments because their allocated shares under the Availability Agreement exceed their allocated shares under the Unit Power Sales Agreement. See discussion below of the Reallocation Agreement among System Energy, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans, pursuant to which Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans assumed all of Entergy Arkansas’s responsibilities and obligations with respect to Grand Gulf under the Availability Agreement. Reallocation Agreement (Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and System Energy) System Energy, Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans entered into the Reallocation Agreement relating to the sale of capacity and energy from Grand Gulf and the related costs, in which Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans agreed to assume all of Entergy Arkansas’s responsibilities and obligations with respect to Grand Gulf under the Availability Agreement. The FERC’s decision allocating a portion of Grand Gulf capacity and energy to Entergy Arkansas supersedes the Reallocation Agreement as it relates to Grand Gulf. However, the Reallocation Agreement does not affect Entergy Arkansas’s obligation to System Energy’s lenders under the assignments referred to in the preceding paragraph. Entergy Arkansas would be liable for its share of such amounts if Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans were unable to meet their contractual obligations. No payments of any amortization amounts will be required so long as amounts paid to System Energy under the Unit Power Sales Agreement, including other funds available to System Energy, exceed amounts required under the Availability Agreement, which is expected to be the case for the foreseeable future. Nelson Industrial Steam Company (Entergy Louisiana) Entergy Louisiana is a partner in the Nelson Industrial Steam Company (NISCO) partnership which owns two petroleum coke generating units. In April 2023 these generating units suspended operations in the MISO market, and Entergy Louisiana currently is working to wind up the NISCO partnership, which will ultimately result in ownership of the generating units transferring to Entergy Louisiana. In November 2023 the FERC issued an order providing Section 203 of the Federal Power Act approval for any subsequent transfer of the facilities to Entergy Louisiana. Entergy Louisiana is evaluating the effect of the transaction on its results of operations, cash flows, and financial condition, but at this time does not expect the effect to be material. NOTE 9. ASSET RETIREMENT OBLIGATIONS Accounting standards require companies to record liabilities for all legal obligations associated with the retirement of long-lived assets that result from the normal operation of the assets. For Entergy, substantially all of its asset retirement obligations consist of its liability for decommissioning its nuclear power plants. In addition, an insignificant amount of removal costs associated with non-nuclear power plants is also included in the decommissioning and asset retirement costs line item on the balance sheets. These liabilities are recorded at their fair values (which are the present values of the estimated future cash outflows) in the period in which they are incurred, with an accompanying addition to the recorded cost of the long-lived asset. The asset retirement obligation is accreted each year through a charge to expense, to reflect the time value of money for this present value obligation. The accretion will continue through the completion of the asset retirement activity. The amounts added to the carrying amounts of the long-lived assets will be depreciated over the useful lives of the assets. The application of accounting standards related to asset retirement obligations is earnings neutral to the rate-regulated business of the Registrant Subsidiaries. The cumulative decommissioning and retirement cost liabilities and expenses recorded in 2023 and 2022 by the Registrant Subsidiaries were as follows:
Coal Combustion Residuals In April 2015 the EPA published the final coal combustion residuals (CCR) rule regulating CCRs destined for disposal in landfills or surface impoundments as non-hazardous wastes regulated under Resource Conservation and Recovery Act Subtitle D. The final regulations create new compliance requirements including modified storage, new notification and reporting practices, product disposal considerations, and CCR unit closure criteria, but excluded CCRs that are beneficially reused in certain processes. Entergy believes that on-site disposal options will be available at its facilities, to the extent needed. In the third quarter 2022, revisions to the Big Cajun 2 CCR asset retirement obligations were made as a result of revised closure and post-closure cost estimates. The revised estimates resulted in increases of $2.8 million at Entergy Louisiana and $2.1 million at Entergy Texas in decommissioning cost liabilities, along with corresponding increases in related asset retirement obligations cost assets that will be depreciated over the remaining useful life of the unit. NOTE 10. LEASES As of December 31, 2023 and 2022, Entergy and the Registrant Subsidiaries held operating and finance leases for fleet vehicles used in operations, real estate, and aircraft. Excluded are power purchase agreements not meeting the definition of a lease, nuclear fuel leases. Leases have remaining terms of one year to 57 years. Real estate leases generally include at least one five-year renewal option; however, renewal is not typically considered reasonably certain unless Entergy or a Registrant Subsidiary makes significant leasehold improvements or other modifications that would hinder its ability to easily move. In certain of the lease agreements for fleet vehicles used in operations, Entergy and the Registrant Subsidiaries provide residual value guarantees to the lessor. Due to the nature of the agreements and Entergy’s continuing relationship with the lessor, however, Entergy and the Registrant Subsidiaries expect to renegotiate or refinance the leases prior to conclusion of the lease. As such, Entergy and the Registrant Subsidiaries do not believe it is probable that they will be required to pay anything pertaining to the residual value guarantee, and the lease liabilities and right-of-use assets are measured accordingly. The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2023:
Of the lease costs disclosed above, Entergy Mississippi had $1.1 million in short-term lease costs for the year ended December 31, 2023. The Registrant Subsidiaries incurred the following lease costs for the year ended December 31, 2022:
Of the lease costs disclosed above, Entergy Mississippi had $0.9 million in short-term lease costs for the year ended December 31, 2022. The lease costs for the years ended December 31, 2023 and 2022 disclosed above materially approximate the cash flows used by the Registrant Subsidiaries for leases with all costs included within operating activities on the respective Statements of Cash Flows, except for the finance lease costs which are included in financing activities. Entergy has elected to account for short-term leases in accordance with policy options provided by accounting guidance; therefore, there are no related lease liabilities or right-of-use assets for the costs recognized above by Entergy or by its Registrant Subsidiaries in the table below. Included within Utility Plant on the Registrant Subsidiaries’ respective balance sheets at December 31, 2023 and 2022 are the following amounts:
The following lease-related liabilities are recorded within the Registrant Subsidiaries’ respective balance sheets at December 31, 2023:
The following lease-related liabilities are recorded within the Registrant Subsidiaries’ respective balance sheets at December 31, 2022:
The following information contains the weighted-average remaining lease term in years and the weighted-average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2023:
The following information contains the weighted-average remaining lease term in years and the weighted-average discount rate for the operating and finance leases of the Registrant Subsidiaries at December 31, 2022:
Maturity of the lease liabilities for the Registrant Subsidiaries as of December 31, 2023 are as follows: Operating Leases
Finance Leases
In allocating consideration in lease contracts to the lease and non-lease components, Entergy and the Registrant Subsidiaries have made the accounting policy election to combine lease and non-lease components related to fleet vehicles used in operations and to allocate the contract consideration to both lease and non-lease components for real estate leases. NOTE 11. RETIREMENT, OTHER POSTRETIREMENT BENEFITS, AND DEFINED CONTRIBUTION PLANS Qualified Pension Plans Entergy has defined benefit qualified pension plans, including the Entergy Corporation Retirement Plan for Non-Bargaining Employees (Non-Bargaining Plan I), the Entergy Corporation Retirement Plan for Bargaining Employees (Bargaining Plan I), the Entergy Corporation Retirement Plan II for Non-Bargaining Employees (Non-Bargaining Plan II), the Entergy Corporation Retirement Plan II for Bargaining Employees (Bargaining Plan II), the Entergy Corporation Retirement Plan III (Plan III), the Entergy Corporation Retirement Plan IV for Bargaining Employees, and the Entergy Corporation Cash Balance Plan for Bargaining Employees (Bargaining Cash Balance Plan). The Entergy Corporation Cash Balance Plan for Non-Bargaining Employees (Non-Bargaining Cash Balance Plan) was merged with and into Non-Bargaining Plan I effective January 1, 2022. Effective January 1, 2024, Non-Bargaining Plan I was amended to spin-off predominately inactive participants into a new qualified pension plan, Entergy Corporation Retirement Plan VI for Non-Bargaining Employees (Non-Bargaining Plan VI). The Registrant Subsidiaries participate in these plans: Non-Bargaining Plan I, Bargaining Plan I, Plan III, Non-Bargaining Plan VI, and Bargaining Cash Balance Plan. Non-bargaining and bargaining employees whose most recent date of hire was prior to June 30, 2014 (or such later date provided for in their applicable collective bargaining agreement) participate in a noncontributory final average pay formula that provides pension benefits based on the employee’s credited service and compensation during employment. Non-bargaining and bargaining employees whose most recent date of hire is after June 30, 2014 and before January 1, 2021 (or such later date provided for in their applicable collective bargaining agreement) do not participate in a final average pay formula, but instead participate in a cash balance formula. Effective January 1, 2021, the Non-Bargaining Cash Balance Plan and Bargaining Cash Balance Plan were amended to close participation in each plan to those employees whose most recent hire date is after December 31, 2020 (or such later date provided for in their applicable collective bargaining agreement). Employees hired after this date instead may be eligible to participate in and receive a discretionary employer contribution under an Entergy sponsored tax-qualified defined contribution plan that includes a 401(k) feature. The assets of the defined benefit qualified pension plans are held in a master trust established by Entergy. Each pension plan has an undivided beneficial interest in each of the investment accounts in the master trust that is maintained by a trustee. Use of the master trust permits the commingling of the trust assets of the pension plans of Entergy Corporation and its Registrant Subsidiaries for investment and administrative purposes. Although assets in the master trust are commingled, the trustee maintains supporting records for the purpose of allocating the trust level equity in net earnings (loss) and the administrative expenses of the investment accounts in the trust to the various participating pension plans in the trust. The fair value of the trust’s assets is determined by the trustee and certain investment managers. The trustee calculates a daily earnings factor, including realized and unrealized gains or losses, collected and accrued income, and administrative expenses, and allocates earnings to each plan in the master trust on a pro rata basis. Within each pension plan, the record of each Registrant Subsidiary’s beneficial interest in the plan assets is maintained by the plan’s actuary and is updated quarterly. Assets for each Registrant Subsidiary are increased for investment net income and contributions and are decreased for benefit payments. A plan’s investment net income/loss (i.e., interest and dividends, realized and unrealized gains and losses and expenses) is allocated to the Registrant Subsidiaries participating in that plan based on the value of assets for each Registrant Subsidiary at the beginning of the quarter adjusted for contributions and benefit payments made during the quarter. Entergy Corporation and its subsidiaries fund pension plans in an amount not less than the minimum required contribution under the Employee Retirement Income Security Act of 1974, as amended, and the Internal Revenue Code of 1986, as amended. The assets of the plans include common and preferred stocks, fixed-income securities, interest in a money market fund, and insurance contracts. The Registrant Subsidiaries’ pension costs are recovered from customers as a component of cost of service in each of their respective jurisdictions. Components of Qualified Net Pension Cost and Other Amounts Recognized as a Regulatory Asset and/or Accumulated Other Comprehensive Income (AOCI) The Registrant Subsidiaries’ total 2023, 2022, and 2021 qualified pension costs and amounts recognized as a regulatory asset and/or other comprehensive income, including amounts capitalized, for their current and former employees included the following components:
Qualified Pension Obligations, Plan Assets, Funded Status, and Amounts Recognized in the Balance Sheet Qualified pension obligations, plan assets, funded status, and amounts recognized in the Balance Sheets for the Registrant Subsidiaries as of December 31, 2023 and 2022 are as follows:
a.Including settlement lump sum benefit payments of ($68.7) million at Entergy Arkansas, ($103.1) million at Entergy Louisiana, ($31.4) million at Entergy Mississippi, ($5.3) million at Entergy New Orleans, ($29.4) million at Entergy Texas, and ($16.7) million at System Energy.
a.Including settlement lump sum benefit payments of ($96) million at Entergy Arkansas, ($146.6) million at Entergy Louisiana, ($48) million at Entergy Mississippi, ($16.2) million at Entergy New Orleans, ($48.9) million at Entergy Texas, and ($23.5) million at System Energy. The qualified pension plans incurred net actuarial gains during 2023 primarily due to asset gains resulting from an actual return on assets much higher than the expected return on assets, offset by liability losses due to a decline in bond yields that resulted in decreases to the discount rates used to develop the benefit obligations. The qualified pension plans incurred a small net actuarial loss during 2022 primarily due to asset losses resulting from an actual return on assets much lower than the expected return on assets, substantially offset by liability gains due to a rise in bond yields that resulted in increases to the discount rates used to develop the benefit obligations. Accumulated Pension Benefit Obligation The qualified pension accumulated benefit obligation for each of the Registrant Subsidiaries for their current and former employees as of December 31, 2023 and 2022 was as follows:
Other Postretirement Benefits Entergy also currently offers retiree medical, dental, vision, and life insurance benefits (other postretirement benefits) for eligible retired employees. Employees who commenced employment before July 1, 2014 and who satisfy certain eligibility requirements (including retiring from Entergy after a certain age and/or years of service with Entergy and immediately commencing their Entergy pension benefit), may become eligible for other postretirement benefits. In March 2020, Entergy announced changes to its other postretirement benefits. Effective January 1, 2021, certain retired, former non-bargaining employees age 65 and older who are eligible for Entergy-sponsored retiree welfare benefits, and their eligible spouses who are age 65 and older (collectively, Medicare-eligible participants), are eligible to participate in an Entergy-sponsored retiree health plan, and are no longer eligible for retiree coverage under the Entergy Corporation Companies’ Benefits Plus Medical, Dental and Vision Plans. Under the Entergy-sponsored retiree health plan, Medicare-eligible participants are eligible to participate in a health reimbursement arrangement which they may use towards the purchase of various types of qualified insurance offered through a Medicare exchange provider and for other qualified medical expenses. The changes affecting active bargaining unit employees were negotiated with the unions prior to implementation, where necessary, and to the extent required by law. Effective January 1, 1993, Entergy adopted an accounting standard requiring a change from a cash method to an accrual method of accounting for postretirement benefits other than pensions. Entergy Arkansas, Entergy Mississippi, Entergy New Orleans, and Entergy Texas have received regulatory approval to recover accrued other postretirement benefits costs through rates. The LPSC ordered Entergy Louisiana to continue the use of the pay-as-you-go method for ratemaking purposes for postretirement benefits other than pensions. However, the LPSC retains the flexibility to examine individual companies’ accounting for other postretirement benefits to determine if special exceptions to this order are warranted. Pursuant to regulatory directives, Entergy Arkansas, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy contribute the other postretirement benefits costs collected in rates into external trusts. System Energy is funding, on behalf of Entergy Operations, other postretirement benefits associated with employees who work or worked at Grand Gulf. Trust assets contributed by participating Registrant Subsidiaries are in master trusts, established by Entergy Corporation and maintained by a trustee. Each participating Registrant Subsidiary holds a beneficial interest in the trusts’ assets. The assets in the master trusts are commingled for investment and administrative purposes. Although assets are commingled, supporting records are maintained for the purpose of allocating the beneficial interest in net earnings/(losses) and the administrative expenses of the investment accounts to the various participating plans and participating Registrant Subsidiaries. Beneficial interest in an investment account’s net income/(loss) is comprised of interest and dividends, realized and unrealized gains and losses, and expenses. Beneficial interest from these investments is allocated to the plans and participating Registrant Subsidiary based on their portion of net assets in the pooled accounts. Components of Net Other Postretirement Benefits Cost and Other Amounts Recognized as a Regulatory Asset and/or AOCI Total 2023, 2022, and 2021 other postretirement benefits costs of the Registrant Subsidiaries, including amounts capitalized and deferred, for their current and former employees included the following components:
Other Postretirement Benefits Obligations, Plan Assets, Funded Status, and Amounts Not Yet Recognized and Recognized in the Balance Sheet Other postretirement benefits obligations, plan assets, funded status, and amounts not yet recognized and recognized in the Balance Sheets of the Registrant Subsidiaries as of December 31, 2023 and 2022 are as follows:
The other postretirement plans incurred net actuarial gains during 2023 primarily due to updated demographic assumptions and census data coupled with an actual return on assets much higher than the expected return on assets, partially offset by liability losses due to a decline in bond yields that resulted in decreases to the discount rates used to develop the benefit obligations. The other postretirement plans incurred net actuarial gains during 2022 primarily due to a rise in bond yields that resulted in increases to the discount rates used to develop the benefit obligations, partially offset by asset losses due to an actual return on assets much lower than the expected return on assets during 2022. Non-Qualified Pension Plans Entergy also sponsors non-qualified, non-contributory defined benefit pension plans that provide benefits to certain key employees. The following Registrant Subsidiaries participate in Entergy’s non-qualified, non-contributory defined benefit pension plans that provide benefits to certain key employees. The net periodic pension cost for their current and former employees for the non-qualified plans for 2023, 2022, and 2021, was as follows:
Included in the 2023 net periodic pension cost above are settlement charges of $379 thousand and $453 thousand for Entergy Arkansas and Entergy Mississippi, respectively, related to the lump sum benefits paid out of the plan. Included in the 2022 net periodic pension cost above are settlement charges of $1 thousand, $2 thousand, and $1 million for Entergy Louisiana, Entergy Mississippi, and Entergy Texas, respectively, related to the lump sum benefits paid out of the plan. Included in the 2021 net periodic pension cost above are settlement charges of $155 thousand and $172 thousand for Entergy Louisiana and Entergy Texas, respectively, related to the lump sum benefits paid out of the plan. The projected benefit obligation for their current and former employees for the non-qualified plans as of December 31, 2023 and 2022 was as follows:
The accumulated benefit obligation for their current and former employees for the non-qualified plans as of December 31, 2023 and 2022 was as follows:
The following amounts were recorded on the balance sheet as of December 31, 2023 and 2022:
The non-qualified pension plans incurred a small actuarial loss during 2023 primarily as a result of liability losses due to differences in recent retirement and lump sum experience relative to actuarial assumptions. The non-qualified pension plans incurred a small actuarial gain during 2022 primarily due to a rise in bond yields that resulted in increases to the discount rates used to develop the benefit obligations, partially offset by differences in recent retirement and lump sum experience relative to actuarial assumptions. Qualified Pension Settlement Cost Year-to-date lump sum benefit payments from Non-Bargaining Plan I, Bargaining Plan I, Non-Bargaining Plan II, and Bargaining Plan II exceeded the sum of the Plans’ service and interest cost, resulting in settlement costs during 2023, 2022, and 2021. In accordance with accounting standards, settlement accounting requires immediate recognition of the portion of previously unrecognized losses associated with the settled portion of the plans’ pension liability. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy participate in one or both of Non-Bargaining Plan I and Bargaining Plan I and incurred settlement costs. Similar to other pension costs, the settlement costs were included with employee labor costs and charged to expense and capital in the same manner that labor costs were charged. Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy New Orleans received regulatory approval to defer the expense portion of settlement costs, with future amortization of the deferred settlement expense over the period in which the expense otherwise would be recorded had the immediate recognition not occurred. Qualified Pension and Other Postretirement Plans’ Assets The Plan Administrator’s trust asset investment strategy is to invest the assets in a manner whereby long-term earnings on the assets (plus cash contributions) provide adequate funding for retiree benefit payments. The mix of assets is based on an optimization study that identifies asset allocation targets in order to achieve the maximum return for an acceptable level of risk, while minimizing the expected contributions and pension and postretirement expense. In the optimization studies, the Plan Administrator formulates assumptions about characteristics, such as expected asset class investment returns, volatility (risk), and correlation coefficients among the various asset classes. The future market assumptions used in the optimization study are determined by examining historical market characteristics of the various asset classes and making adjustments to reflect future conditions expected to prevail over the study period. The target asset allocation for pension adjusts dynamically based on the funded status of each plan within the trust. The current targets are shown below. The expectation is that the allocation to fixed income securities will increase as the pension plans’ funded status increases. The following ranges were established to produce an acceptable, economically efficient plan to manage around the targets. For postretirement assets the target and range asset allocations (as shown below) reflect recommendations made in the latest optimization study. The target asset allocations for postretirement assets adjust dynamically based on the funded status of each sub-account within each trust. The current weighted-average targets shown below represent the aggregate of all targets for all sub-accounts within all trusts. Entergy’s qualified pension and postretirement weighted-average asset allocations by asset category at December 31, 2023 and 2022 and the target asset allocation and ranges for 2023 are as follows:
In determining its expected long-term rate of return on plan assets used in the calculation of benefit plan costs, Entergy reviews past performance, current and expected future asset allocations, and capital market assumptions of its investment consultant and some investment managers. The expected long-term rate of return for the qualified pension plans’ assets is based primarily on the geometric average of the historical annual performance of a representative portfolio weighted by the target asset allocation defined in the table above, along with other indications of expected return on assets. The time period reflected is a long-dated period spanning several decades. The expected long-term rate of return for the non-taxable postretirement trust assets is determined using the same methodology described above for pension assets, but the aggregate asset allocation specific to the non-taxable postretirement assets is used. For the taxable postretirement trust assets, the investment allocation includes tax-exempt fixed income securities. This asset allocation, in combination with the same methodology employed to determine the expected return for other postretirement assets (as described above), and with a modification to reflect applicable taxes, is used to produce the expected long-term rate of return for taxable postretirement trust assets. Concentrations of Credit Risk Entergy’s investment guidelines mandate the avoidance of risk concentrations. Types of concentrations specified to be avoided include, but are not limited to, investment concentrations in a single entity, type of industry, foreign country, geographic area, and individual security issuance. As of December 31, 2023, all investment managers and assets were materially in compliance with the approved investment guidelines, therefore there were no significant concentrations (defined as greater than 10 percent of plan assets) of credit risk in Entergy’s pension and other postretirement benefits plan assets. Fair Value Measurements Accounting standards provide the framework for measuring fair value. That framework provides a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurements) and the lowest priority to unobservable inputs (Level 3 measurements). The three levels of the fair value hierarchy are described below: •Level 1 - Level 1 inputs are unadjusted quoted prices for identical assets or liabilities in active markets that the Plan has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. •Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date. Assets are valued based on prices derived by an independent party that uses inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads. Prices are reviewed and can be challenged with the independent parties and/or overridden if it is believed such would be more reflective of fair value. Level 2 inputs include the following: - quoted prices for similar assets or liabilities in active markets; - quoted prices for identical assets or liabilities in inactive markets; - inputs other than quoted prices that are observable for the asset or liability; or - inputs that are derived principally from or corroborated by observable market data by correlation or other means. If an asset or liability has a specified (contractual) term, the Level 2 input must be observable for substantially the full term of the asset or liability. •Level 3 - Level 3 refers to securities valued based on significant unobservable inputs. Assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. The following tables set forth by level within the fair value hierarchy, measured at fair value on a recurring basis at December 31, 2023, and December 31, 2022, a summary of the investments held in the master trusts for Entergy’s qualified pension and other postretirement plans in which the Registrant Subsidiaries participate. Qualified Defined Benefit Pension Plan Trusts
Other Postretirement Trusts
a.Certain fixed income debt securities (corporate, government, and securitized) are stated at fair value as determined by broker quotes. b.Common stocks, preferred stocks, and certain fixed income debt securities (government) are stated at fair value determined by quoted market prices. c.The common collective trusts hold investments in accordance with stated objectives. The investment strategy of the trusts is to capture the growth potential of equity markets by replicating the performance of a specified index. The issuer of these funds allows daily trading at the net asset value and trades settle at a later date, with no other trading restrictions. Net asset value per share of common collective trusts estimate fair value. Common collective trusts are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table, but are included in the total. d.Registered investment companies are money market mutual funds with a stable net asset value of one dollar per share. Registered investment companies may hold investments in domestic and international bond markets or domestic equities valued at the daily closing price as reported by the fund. These funds are required to publish their daily net asset value and to transact at that price. The money market mutual funds held by the trusts are deemed to be actively traded. Certain registered investment companies are recorded at contract value, which approximates fair value. e.Certain of these registered investment companies are not publicly quoted and are valued by the fund administrators using net asset value as a practical expedient. The issuer of these funds allows daily trading at the net asset value and trades settle at a later date, with no other trading restrictions. Accordingly, these funds are not assigned a level in the fair value table, but are included in the total. f.The other remaining assets are U.S. municipal and foreign government bonds stated at fair value as determined by broker quotes. g.The unallocated insurance contract investments are recorded at contract value, which approximates fair value. The contract value represents contributions made under the contract, plus interest, less funds used to pay benefits and contract expenses, and less distributions to the master trust. Estimated Future Benefit Payments Based upon the assumptions used to measure Entergy’s qualified pension and other postretirement benefits obligations at December 31, 2023, and including pension and other postretirement benefits attributable to estimated future employee service, Entergy expects that benefits to be paid over the next ten years for the Registrant Subsidiaries for their current and former employees will be as follows:
Contributions The Registrant Subsidiaries expect to contribute approximately the following to the qualified pension and other postretirement plans for their current and former employees in 2024:
Actuarial Assumptions The significant actuarial assumptions used in determining the pension PBO and the other postretirement benefits APBO as of December 31, 2023 and 2022 were as follows:
The significant actuarial assumptions used in determining the net periodic pension and other postretirement benefits costs for 2023, 2022, and 2021 were as follows:
With respect to the mortality assumptions, Entergy used the Pri-2012 Employee and Healthy Annuitant Table, projected generationally using Scale MP-2021 with Aon’s Endemic Adjustment, in determining its December 31, 2023 pension plans’ PBOs and the Pri.H 2012 (headcount weighted) Employee and Healthy Annuitant Table, projected generationally using Scale MP-2021 with Aon’s Endemic Adjustment, in determining its December 31, 2023 other postretirement benefits APBO. With respect to the mortality assumptions, Entergy used the Pri-2012 Employee and Healthy Annuitant Tables with a fully generational MP-2020 projection scale, in determining its December 31, 2022 pension plans’ PBOs and the Pri.H 2012 (headcount weighted) Employee and Healthy Annuitant Tables with a fully generational MP-2020 projection scale, in determining its December 31, 2022 other postretirement benefits APBO. Defined Contribution Plans Entergy sponsors the Savings Plan of Entergy Corporation and Subsidiaries (System Savings Plan). The System Savings Plan is a defined contribution plan covering eligible employees of Entergy and certain of its subsidiaries. The participating Entergy subsidiary makes matching contributions to the System Savings Plan for all eligible participating employees in an amount equal to either 70% or 100% of the participants’ basic contributions, up to 6% of their eligible earnings per pay period. The matching contribution is allocated to investments as directed by the employee. Entergy also sponsors the Savings Plan of Entergy Corporation and Subsidiaries VI (Savings Plan VI) (established in April 2007) and the Savings Plan of Entergy Corporation and Subsidiaries VII (Savings Plan VII) (established in April 2007) to which matching contributions are also made. The plans are defined contribution plans that cover eligible employees, as defined by each plan, of Entergy and certain of its subsidiaries. Effective December 31, 2023, employees participating in Savings Plan VI and Savings Plan VII were transferred into the System Savings Plan when Savings Plan VI and Savings Plan VII merged into the System Savings Plan. Entergy also sponsors the Savings Plan of Entergy Corporation and Subsidiaries VIII (established January 2021) and the Savings Plan of Entergy Corporation and Subsidiaries IX (established January 2021) to which company contributions are made. The participating Entergy subsidiary makes matching contributions to these defined contribution plans for all eligible participating employees in an amount equal to 100% of the participants’ basic contributions, up to 5% of their eligible earnings per pay period. Eligible participants may also receive a discretionary annual company contribution up to 4% of the participant’s eligible earnings (subject to vesting). The Registrant Subsidiaries’ 2023, 2022, and 2021 contributions to defined contribution plans for their employees were as follows:
NOTE 12. STOCK-BASED COMPENSATION Note 12 to the financial statements is not applicable to the Registrant Subsidiaries. NOTE 13. BUSINESS SEGMENT INFORMATION Registrant Subsidiaries Each of the Registrant Subsidiaries has one reportable segment, which is an integrated utility business, except for System Energy, which is an electricity generation business. Each of the Registrant Subsidiaries’ operations are managed on an integrated basis by that company because of the substantial effect of cost-based rates and regulatory oversight on the business process, cost structures, and operating results. Management allocates resources and assesses financial performance on a consolidated basis. NOTE 14. ACQUISITIONS AND DISPOSITIONS Acquisitions Sunflower Solar In November 2018, Entergy Mississippi entered into an agreement for the purchase of an approximately 100 MW solar photovoltaic facility to be sited on approximately 1,000 acres in Sunflower County, Mississippi. The project, Sunflower Solar facility, was being built by Sunflower County Solar Project, LLC, an indirect subsidiary of Recurrent Energy, LLC. In December 2018, Entergy Mississippi filed a joint petition with Sunflower County Solar Project with the MPSC for Sunflower County Solar Project to construct and for Entergy Mississippi to acquire and thereafter own, operate, improve, and maintain the solar facility. In March 2020, Entergy Mississippi filed supplemental testimony addressing questions and observations raised in August 2019 by consultants retained by the Mississippi Public Utilities Staff and proposing an alternative structure for the transaction that would reduce its cost. In April 2020 the MPSC issued an order approving certification of the Sunflower Solar facility, subject to certain conditions, including: (i) that Entergy Mississippi pursue a tax equity partnership structure through which the partnership would acquire and own the facility under the build-own-transfer agreement and (ii) that if Entergy Mississippi does not consummate the partnership structure under the terms of the order, there will be a cap of $136 million on the level of recoverable costs. In April 2022, Entergy Mississippi confirmed mechanical completion of the Sunflower Solar facility. Pursuant to the MPSC’s April 2020 order, MS Sunflower Partnership, LLC was formed for the tax equity partnership with Entergy Mississippi as its managing member. In May 2022 both Entergy Mississippi and the tax equity investor made capital contributions to the tax equity partnership that were then used to make an initial payment of $105 million for acquisition of the facility. Substantial completion of the Sunflower Solar facility was accepted by Entergy Mississippi in September 2022. Commercial operation at the Sunflower Solar facility commenced in September 2022. In April 2023 both Entergy Mississippi and the tax equity investor made additional capital contributions to the tax equity partnership that were then used to make the substantial completion payment of $30 million for acquisition of the facility. The final payment of $5 million for acquisition of the facility was made in October 2023. NOTE 15. RISK MANAGEMENT AND FAIR VALUES Market Risk In the normal course of business, Entergy is exposed to a number of market risks. Market risk is the potential loss that Entergy may incur as a result of changes in the market or fair value of a particular commodity or instrument. All financial and commodity-related instruments, including derivatives, are subject to market risk including commodity price risk, equity price, and interest rate risk. Entergy uses derivatives primarily to mitigate commodity price risk, particularly power price and fuel price risk. The Utility has limited exposure to the effects of market risk because it operates primarily under cost-based rate regulation. To the extent approved by their retail regulators, the Utility operating companies use derivative instruments to hedge the exposure to price volatility inherent in their purchased power, fuel, and gas purchased for resale costs, that are recovered from customers. Entergy’s exposure to market risk is determined by a number of factors, including the size, term, composition, and diversification of positions held, as well as market volatility and liquidity. For instruments such as options, the time period during which the option may be exercised and the relationship between the current market price of the underlying instrument and the option’s contractual strike or exercise price also affects the level of market risk. A significant factor influencing the overall level of market risk to which Entergy is exposed is its use of hedging techniques to mitigate such risk. Hedging instruments and volumes are chosen based on ability to mitigate risk associated with future energy and capacity prices; however, other considerations are factored into hedge product and volume decisions including corporate liquidity, corporate credit ratings, counterparty credit risk, hedging costs, firm settlement risk, and product availability in the marketplace. Entergy manages market risk by actively monitoring compliance with stated risk management policies as well as monitoring the effectiveness of its hedging policies and strategies. Entergy’s risk management policies limit the amount of total net exposure and rolling net exposure during the stated periods. These policies, including related risk limits, are regularly assessed to ensure their appropriateness given Entergy’s objectives. Derivatives Some derivative instruments are classified as cash flow hedges due to their financial settlement provisions while others are classified as normal purchase/normal sale transactions due to their physical settlement provisions. Normal purchase/normal sale risk management tools include power purchase and sales agreements, fuel purchase agreements, capacity contracts, and tolling agreements. Financially-settled cash flow hedges can include natural gas and electricity swaps and options. Entergy may enter into financially-settled swap and option contracts to manage market risk that may or may not be designated as hedging instruments. Entergy entered into derivatives to manage natural risks inherent in its physical or financial assets or liabilities. Electricity over-the-counter instruments and futures contracts that financially settled against day-ahead power pool prices were used to manage price exposure for the non-utility operations’ generation. Entergy manages fuel price volatility for its Louisiana jurisdictions (Entergy Louisiana and Entergy New Orleans) and Entergy Mississippi through the purchase of natural gas swaps and options that financially settle against either the average Henry Hub Gas Daily prices or the NYMEX Henry Hub. These swaps and options are marked-to-market through fuel expense with offsetting regulatory assets or liabilities. All benefits or costs of the program are recorded in fuel costs. The notional volumes of these swaps are based on a portion of projected annual exposure to gas price volatility for electric generation at Entergy Louisiana and Entergy Mississippi and projected winter purchases for gas distribution at Entergy New Orleans. The maximum length of time over which Entergy has executed natural gas swaps and options as of December 31, 2023 is 3 months for Entergy Louisiana, 10 months for Entergy Mississippi, and 3 months for Entergy New Orleans. The total volume of natural gas swaps and options outstanding as of December 31, 2023 is 14,798,500 MMBtu for Entergy, including 1,820,000 MMBtu for Entergy Louisiana, 12,491,700 MMBtu for Entergy Mississippi, and 486,800 MMBtu for Entergy New Orleans. Credit support for these natural gas swaps and options is covered by master agreements that do not require Entergy to provide collateral based on mark-to-market value, but do carry adequate assurance language that may lead to requests for collateral. During the second quarter 2023, Entergy participated in the annual financial transmission rights auction process for the MISO planning year of June 1, 2023 through May 31, 2024. Financial transmission rights are derivative instruments that represent economic hedges of future congestion charges that will be incurred in serving Entergy’s customer load. They are not designated as hedging instruments. Entergy initially records financial transmission rights at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period prior to settlement. Unrealized gains or losses on financial transmission rights held by the non-utility operations are included in operating revenues. The Utility operating companies recognize regulatory liabilities or assets for unrealized gains or losses on financial transmission rights. The total volume of financial transmission rights outstanding as of December 31, 2023 is 62,809 GWh for Entergy, including 15,385 GWh for Entergy Arkansas, 26,990 GWh for Entergy Louisiana, 8,250 GWh for Entergy Mississippi, 2,478 GWh for Entergy New Orleans, and 9,611 GWh for Entergy Texas. Credit support for financial transmission rights held by the Utility operating companies is covered by cash and/or letters of credit issued by each Utility operating company as required by MISO. Credit support for financial transmission rights held by the non-utility operations business is covered by cash. No cash or letters of credit were required to be posted for financial transmission rights exposure for the non-utility operations business as of December 31, 2023 and 2022. Letters of credit posted with MISO covered the financial transmission rights exposure for Entergy Arkansas, Entergy Louisiana, Entergy Mississippi, and Entergy Texas as of December 31, 2023 and for Entergy Mississippi, Entergy New Orleans, and Entergy Texas as of December 31, 2022. The fair values of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ balance sheets as of December 31, 2023 and 2022 are shown in the table below. Certain investments, including those not designated as hedging instruments, are subject to master netting agreements and are presented in the balance sheet on a net basis in accordance with accounting guidance for derivatives and hedging.
a.Represents the gross amounts of recognized assets/liabilities b.Represents the netting of fair value balances with the same counterparty c.Represents the net amounts of assets/liabilities presented on the Registrant Subsidiaries’ balance sheets d.As of December 31, 2023, letters of credit posted with MISO covered financial transmission rights exposure of $1.2 million for Entergy Arkansas, $0.5 million for Entergy Louisiana, $0.3 million for Entergy Mississippi, and $0.1 million for Entergy Texas. As of December 31, 2022, letters of credit posted with MISO covered financial transmission rights exposure of $0.2 million for Entergy Mississippi, $0.2 million for Entergy New Orleans, and $2.4 million for Entergy Texas. The effects of derivative instruments not designated as hedging instruments on the Registrant Subsidiaries’ income statements for the years ended December 31, 2023, 2022, and 2021 are as follows:
a.Due to regulatory treatment, the natural gas swaps and options are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as fuel expenses when the swaps and options are settled are recovered or refunded through fuel cost recovery mechanisms. b.Due to regulatory treatment, the changes in the estimated fair value of financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability. The gains or losses recorded as purchased power expense when the financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms. Fair Values The estimated fair values of Entergy’s financial instruments and derivatives are determined using historical prices, bid prices, market quotes, and financial modeling. Considerable judgment is required in developing the estimates of fair value. Therefore, estimates are not necessarily indicative of the amounts that Entergy could realize in a current market exchange. Gains or losses realized on financial instruments are reflected in future rates and therefore do not affect net income. Entergy considers the carrying amounts of most financial instruments classified as current assets and liabilities to be a reasonable estimate of their fair value because of the short maturity of these instruments. Accounting standards define fair value as an exit price, or the price that would be received to sell an asset or the amount that would be paid to transfer a liability in an orderly transaction between knowledgeable market participants at the date of measurement. Entergy and the Registrant Subsidiaries use assumptions or market input data that market participants would use in pricing assets or liabilities at fair value. The inputs can be readily observable, corroborated by market data, or generally unobservable. Entergy and the Registrant Subsidiaries endeavor to use the best available information to determine fair value. Accounting standards establish a fair value hierarchy that prioritizes the inputs used to measure fair value. The hierarchy establishes the highest priority for unadjusted market quotes in an active market for the identical asset or liability and the lowest priority for unobservable inputs. The three levels of the fair value hierarchy are: •Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas swaps traded on exchanges with active markets. Cash equivalents includes all unrestricted highly liquid debt instruments with an original or remaining maturity of three months or less at the date of purchase. •Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date. Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads. Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value. Level 2 inputs include the following: –quoted prices for similar assets or liabilities in active markets; –quoted prices for identical assets or liabilities in inactive markets; –inputs other than quoted prices that are observable for the asset or liability; or –inputs that are derived principally from or corroborated by observable market data by correlation or other means. Level 2 consists primarily of individually-owned debt instruments and gas swaps and options valued using observable inputs. •Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources. These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability. Level 3 consists primarily of financial transmission rights. As a result of the completion of Entergy’s strategy to exit the merchant nuclear power business, which included the shut down and sale of all non-utility nuclear plants, the portfolio of derivative instruments held by Entergy’s non-utility operations business expired in April 2021, which was the settlement date for the last financial derivative contracts in the non-utility operations business’ portfolio. The values for power contract assets or liabilities prior to expiration in April 2021 were based on both observable inputs including public market prices and interest rates, and unobservable inputs such as implied volatilities, unit contingent discounts, expected basis differences, and credit adjusted counterparty interest rates. They were classified as Level 3 assets and liabilities. The valuations of these assets and liabilities were performed by the Office of Corporate Risk Oversight and the non-utility operations Accounting group. The primary related functions of the Office of Corporate Risk Oversight included: gathering, validating, and reporting market data, providing market risk analyses and valuations in support of the non-utility operations commercial transactions, developing and administering protocols for the management of market risks, and implementing and maintaining controls around changes to market data in the energy trading and risk management system. The Office of Corporate Risk Oversight was also responsible for managing the energy trading and risk management system, forecasting revenues, forward positions, and analysis. The non-utility operations Accounting group performed functions related to market and counterparty settlements, revenue reporting and analysis, and financial accounting. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer while the non-utility operations Accounting group reports to the Chief Accounting Officer. The amounts reflected as the fair value of electricity swaps were based on the estimated amount that the contracts were in-the-money at the balance sheet date (treated as an asset) or out-of-the-money at the balance sheet date (treated as a liability) and equaled the estimated amount receivable to or payable by Entergy if the contracts were settled at that date. These derivative contracts included cash flow hedges that swapped fixed for floating cash flows for sales of the output from the non-utility operations business. The fair values were based on the mark-to-market comparison between the fixed contract prices and the floating prices determined each period from quoted forward power market prices. The differences between the fixed price in the swap contract and these market-related prices multiplied by the volume specified in the contract and discounted at the counterparties’ credit adjusted risk free rate were recorded as derivative contract assets or liabilities. For contracts that had unit contingent terms, a further discount was applied based on the historical relationship between contract and market prices for similar contract terms. The amounts reflected as the fair values of electricity options were valued based on a Black Scholes model and were calculated at the end of each month for accounting purposes. Inputs to the valuation included end of day forward market prices for the period when the transactions settled, implied volatilities based on market volatilities provided by a third-party data aggregator, and U.S. Treasury rates for a risk-free return rate. As described further below, prices and implied volatilities were reviewed and could be adjusted if it was determined that there was a better representation of fair value. On a daily basis, the Office of Corporate Risk Oversight calculated the mark-to-market for electricity swaps and options. The Office of Corporate Risk Oversight also validated forward market prices by comparing them to other sources of forward market prices or to settlement prices of actual market transactions. Significant differences were analyzed and potentially adjusted based on these other sources of forward market prices or settlement prices of actual market transactions. Implied volatilities used to value options were also validated using actual counterparty quotes for transactions by the non-utility operations business when available and compared with other sources of market implied volatilities. Moreover, on a quarterly basis, the Office of Corporate Risk Oversight confirmed the mark-to-market calculations and prepared price scenarios and credit downgrade scenario analysis. The scenario analysis was communicated to senior management within Entergy. Finally, for all proposed derivative transactions, an analysis was completed to assess the risk of adding the proposed derivative to the non-utility operations business’ portfolio. In particular, the credit and liquidity effects were calculated for this analysis. This analysis was communicated to senior management within Entergy. The values of financial transmission rights are based on unobservable inputs, including estimates of congestion costs in MISO between applicable generation and load pricing nodes based on the 50th percentile of historical prices. They are classified as Level 3 assets and liabilities. The valuations of these assets and liabilities are performed by the Office of Corporate Risk Oversight. The values are calculated internally and verified against the data published by MISO. Entergy’s Accounting group reviews these valuations for reasonableness, with the assistance of others within the organization with knowledge of the various inputs and assumptions used in the valuation. The Office of Corporate Risk Oversight reports to the Vice President and Treasurer. The Accounting group reports to the Chief Accounting Officer. The following table sets forth, by level within the fair value hierarchy, the Registrant Subsidiaries’ assets and liabilities that are accounted for at fair value on a recurring basis as of December 31, 2023 and December 31, 2022. The assessment of the significance of a particular input to a fair value measurement requires judgment and may affect placement within the fair value hierarchy levels. Entergy Mississippi
The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the year ended December 31, 2023.
The following table sets forth a reconciliation of changes in the net assets for the fair value of derivatives classified as Level 3 in the fair value hierarchy for the year ended December 31, 2022.
NOTE 16. DECOMMISSIONING TRUST FUNDS Note 16 to the financial statements is not applicable to Entergy Mississippi. NOTE 17. VARIABLE INTEREST ENTITIES Note 17 to the financial statements is not applicable to the presentation of the FERC Form 1. NOTE 18. TRANSACTIONS WITH AFFILIATES Each Registrant Subsidiary purchases electricity from or sells electricity to the other Registrant Subsidiaries, or both, under rate schedules filed with the FERC. The Registrant Subsidiaries receive management, technical, advisory, operating, and administrative services from Entergy Services; and receive management, technical, and operating services from Entergy Operations. These transactions are on an “at cost” basis. The tables below contain the various affiliate transactions of the Utility operating companies, System Energy, and other Entergy affiliates. Intercompany Revenues
Intercompany Operating Expenses
Intercompany Interest and Investment Income
NOTE 19. SUBSEQUENT EVENTS Management has evaluated the impact of events occurring after December 31, 2023 up to February 23, 2024, the date that Entergy Mississippi's U.S. GAAP financial statements were issued and has updated such evaluation for disclosure purposes through April 15, 2024. These financial statements include all necessary adjustments and disclosures resulting from these evaluations. |
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Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
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STATEMENTS OF ACCUMULATED COMPREHENSIVE INCOME, COMPREHENSIVE INCOME, AND HEDGING ACTIVITIES |
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| Line No. |
Item (a) |
Unrealized Gains and Losses on Available-For-Sale Securities (b) |
Minimum Pension Liability Adjustment (net amount) (c) |
Foreign Currency Hedges (d) |
Other Adjustments (e) |
Other Cash Flow Hedges Interest Rate Swaps (f) |
Other Cash Flow Hedges [Specify] (g) |
Totals for each category of items recorded in Account 219 (h) |
Net Income (Carried Forward from Page 116, Line 78) (i) |
Total Comprehensive Income (j) |
| 1 | Balance of Account 219 at Beginning of Preceding Year |
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| 2 | Preceding Quarter/Year to Date Reclassifications from Account 219 to Net Income |
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| 3 | Preceding Quarter/Year to Date Changes in Fair Value |
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| 4 | Total (lines 2 and 3) |
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| 5 | Balance of Account 219 at End of Preceding Quarter/Year |
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| 6 | Balance of Account 219 at Beginning of Current Year |
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| 7 | Current Quarter/Year to Date Reclassifications from Account 219 to Net Income |
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| 8 | Current Quarter/Year to Date Changes in Fair Value |
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| 9 | Total (lines 7 and 8) |
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| 10 | Balance of Account 219 at End of Current Quarter/Year |
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Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
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SUMMARY OF UTILITY PLANT AND ACCUMULATED PROVISIONS FOR DEPRECIATION. AMORTIZATION AND DEPLETION |
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Report in Column (c) the amount for electric function, in column (d) the amount for gas function, in column (e), (f), and (g) report other (specify) and in column (h) common function. |
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| Line No. |
Classification (a) |
Total Company For the Current Year/Quarter Ended (b) |
Electric (c) |
Gas (d) |
Other (Specify) (e) |
Other (Specify) (f) |
Other (Specify) (g) |
Common (h) |
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1 |
UtilityPlantAbstract UTILITY PLANT |
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2 |
UtilityPlantInServiceAbstract In Service |
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3 |
UtilityPlantInServiceClassified Plant in Service (Classified) |
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4 |
UtilityPlantInServicePropertyUnderCapitalLeases Property Under Capital Leases |
(a) |
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5 |
UtilityPlantInServicePlantPurchasedOrSold Plant Purchased or Sold |
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6 |
UtilityPlantInServiceCompletedConstructionNotClassified Completed Construction not Classified |
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7 |
UtilityPlantInServiceExperimentalPlantUnclassified Experimental Plant Unclassified |
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8 |
UtilityPlantInServiceClassifiedAndUnclassified Total (3 thru 7) |
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9 |
UtilityPlantLeasedToOthers Leased to Others |
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10 |
UtilityPlantHeldForFutureUse Held for Future Use |
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11 |
ConstructionWorkInProgress Construction Work in Progress |
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12 |
UtilityPlantAcquisitionAdjustment Acquisition Adjustments |
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13 |
UtilityPlantAndConstructionWorkInProgress Total Utility Plant (8 thru 12) |
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14 |
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility Accumulated Provisions for Depreciation, Amortization, & Depletion |
(b) |
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15 |
UtilityPlantNet Net Utility Plant (13 less 14) |
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16 |
DetailOfAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract DETAIL OF ACCUMULATED PROVISIONS FOR DEPRECIATION, AMORTIZATION AND DEPLETION |
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17 |
AccumulatedProvisionForDepreciationAmortizationAndDepletionUtilityPlantInServiceAbstract In Service: |
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18 |
DepreciationUtilityPlantInService Depreciation |
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19 |
AmortizationAndDepletionOfProducingNaturalGasLandAndLandRightsutilityPlantInService Amortization and Depletion of Producing Natural Gas Land and Land Rights |
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20 |
AmortizationOfUndergroundStorageLandAndLandRightsutilityPlantInService Amortization of Underground Storage Land and Land Rights |
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21 |
AmortizationOfOtherUtilityPlantUtilityPlantInService Amortization of Other Utility Plant |
(c) |
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22 |
DepreciationAmortizationAndDepletionUtilityPlantInService Total in Service (18 thru 21) |
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23 |
DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthersAbstract Leased to Others |
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24 |
DepreciationUtilityPlantLeasedToOthers Depreciation |
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25 |
AmortizationAndDepletionUtilityPlantLeasedToOthers Amortization and Depletion |
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26 |
DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthers Total Leased to Others (24 & 25) |
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27 |
DepreciationAndAmortizationUtilityPlantHeldForFutureUseAbstract Held for Future Use |
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28 |
DepreciationUtilityPlantHeldForFutureUse Depreciation |
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29 |
AmortizationUtilityPlantHeldForFutureUse Amortization |
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30 |
DepreciationAndAmortizationUtilityPlantHeldForFutureUse Total Held for Future Use (28 & 29) |
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31 |
AbandonmentOfLeases Abandonment of Leases (Natural Gas) |
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32 |
AmortizationOfPlantAcquisitionAdjustment Amortization of Plant Acquisition Adjustment |
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33 |
AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility Total Accum Prov (equals 14) (22,26,30,31,32) |
(d) |
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Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: UtilityPlantInServicePropertyUnderCapitalLeases |
| (b) Concept: AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility |
| (c) Concept: AmortizationOfOtherUtilityPlantUtilityPlantInService |
| (d) Concept: AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility |
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Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
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NUCLEAR FUEL MATERIALS (Account 120.1 through 120.6 and 157) |
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| Line No. |
Description of item (a) |
Balance Beginning of Year (b) |
Changes during Year Additions (c) |
Changes during Year Amortization (d) |
Changes during Year Other Reductions (Explain in a footnote) (e) |
Balance End of Year (f) |
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1 |
Nuclear Fuel in process of Refinement, Conv, Enrichment & Fab (120.1) |
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2 |
Fabrication |
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3 |
Nuclear Materials |
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4 |
Allowance for Funds Used during Construction |
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5 |
(Other Overhead Construction Costs, provide details in footnote) |
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6 |
SUBTOTAL (Total 2 thru 5) |
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7 |
Nuclear Fuel Materials and Assemblies |
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8 |
In Stock (120.2) |
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9 |
In Reactor (120.3) |
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10 |
SUBTOTAL (Total 8 & 9) |
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11 |
Spent Nuclear Fuel (120.4) |
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12 |
Nuclear Fuel Under Capital Leases (120.6) |
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13 |
(Less) Accum Prov for Amortization of Nuclear Fuel Assem (120.5) |
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14 |
TOTAL Nuclear Fuel Stock (Total 6, 10, 11, 12, less 13) |
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15 |
Estimated Net Salvage Value of Nuclear Materials in Line 9 |
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16 |
Estimated Net Salvage Value of Nuclear Materials in Line 11 |
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17 |
Est Net Salvage Value of Nuclear Materials in Chemical Processing |
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18 |
Nuclear Materials held for Sale (157) |
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19 |
Uranium |
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20 |
Plutonium |
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21 |
Other (Provide details in footnote) |
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22 |
TOTAL Nuclear Materials held for Sale (Total 19, 20, and 21) |
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Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
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ELECTRIC PLANT IN SERVICE (Account 101, 102, 103 and 106) |
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| Line No. |
Account (a) |
Balance Beginning of Year (b) |
Additions (c) |
Retirements (d) |
Adjustments (e) |
Transfers (f) |
Balance at End of Year (g) |
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1 |
1. INTANGIBLE PLANT |
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2 |
(301) Organization |
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3 |
(302) Franchise and Consents |
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4 |
(303) Miscellaneous Intangible Plant |
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5 |
TOTAL Intangible Plant (Enter Total of lines 2, 3, and 4) |
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6 |
2. PRODUCTION PLANT |
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7 |
A. Steam Production Plant |
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8 |
(310) Land and Land Rights |
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9 |
(311) Structures and Improvements |
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10 |
(312) Boiler Plant Equipment |
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11 |
(313) Engines and Engine-Driven Generators |
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12 |
(314) Turbogenerator Units |
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13 |
(315) Accessory Electric Equipment |
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14 |
(316) Misc. Power Plant Equipment |
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15 |
(317) Asset Retirement Costs for Steam Production |
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16 |
TOTAL Steam Production Plant (Enter Total of lines 8 thru 15) |
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17 |
B. Nuclear Production Plant |
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18 |
(320) Land and Land Rights |
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19 |
(321) Structures and Improvements |
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20 |
(322) Reactor Plant Equipment |
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21 |
(323) Turbogenerator Units |
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22 |
(324) Accessory Electric Equipment |
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23 |
(325) Misc. Power Plant Equipment |
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24 |
(326) Asset Retirement Costs for Nuclear Production |
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25 |
TOTAL Nuclear Production Plant (Enter Total of lines 18 thru 24) |
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26 |
C. Hydraulic Production Plant |
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27 |
(330) Land and Land Rights |
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28 |
(331) Structures and Improvements |
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29 |
(332) Reservoirs, Dams, and Waterways |
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30 |
(333) Water Wheels, Turbines, and Generators |
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31 |
(334) Accessory Electric Equipment |
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32 |
(335) Misc. Power Plant Equipment |
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33 |
(336) Roads, Railroads, and Bridges |
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34 |
(337) Asset Retirement Costs for Hydraulic Production |
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35 |
TOTAL Hydraulic Production Plant (Enter Total of lines 27 thru 34) |
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36 |
D. Other Production Plant |
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37 |
(340) Land and Land Rights |
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38 |
(341) Structures and Improvements |
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39 |
(342) Fuel Holders, Products, and Accessories |
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40 |
(343) Prime Movers |
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41 |
(344) Generators |
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42 |
(345) Accessory Electric Equipment |
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43 |
(346) Misc. Power Plant Equipment |
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44 |
(347) Asset Retirement Costs for Other Production |
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44.1 |
(348) Energy Storage Equipment - Production |
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45 |
TOTAL Other Prod. Plant (Enter Total of lines 37 thru 44) |
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46 |
TOTAL Prod. Plant (Enter Total of lines 16, 25, 35, and 45) |
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47 |
3. Transmission Plant |
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48 |
(350) Land and Land Rights |
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48.1 |
(351) Energy Storage Equipment - Transmission |
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49 |
(352) Structures and Improvements |
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50 |
(353) Station Equipment |
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51 |
(354) Towers and Fixtures |
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52 |
(355) Poles and Fixtures |
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53 |
(356) Overhead Conductors and Devices |
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54 |
(357) Underground Conduit |
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55 |
(358) Underground Conductors and Devices |
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56 |
(359) Roads and Trails |
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57 |
(359.1) Asset Retirement Costs for Transmission Plant |
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58 |
TOTAL Transmission Plant (Enter Total of lines 48 thru 57) |
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59 |
4. Distribution Plant |
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60 |
(360) Land and Land Rights |
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61 |
(361) Structures and Improvements |
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62 |
(362) Station Equipment |
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63 |
(363) Energy Storage Equipment – Distribution |
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64 |
(364) Poles, Towers, and Fixtures |
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65 |
(365) Overhead Conductors and Devices |
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66 |
(366) Underground Conduit |
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67 |
(367) Underground Conductors and Devices |
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68 |
(368) Line Transformers |
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69 |
(369) Services |
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70 |
(370) Meters |
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71 |
(371) Installations on Customer Premises |
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72 |
(372) Leased Property on Customer Premises |
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73 |
(373) Street Lighting and Signal Systems |
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74 |
(374) Asset Retirement Costs for Distribution Plant |
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75 |
TOTAL Distribution Plant (Enter Total of lines 60 thru 74) |
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76 |
5. REGIONAL TRANSMISSION AND MARKET OPERATION PLANT |
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77 |
(380) Land and Land Rights |
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78 |
(381) Structures and Improvements |
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79 |
(382) Computer Hardware |
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80 |
(383) Computer Software |
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81 |
(384) Communication Equipment |
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82 |
(385) Miscellaneous Regional Transmission and Market Operation Plant |
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83 |
(386) Asset Retirement Costs for Regional Transmission and Market Oper |
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84 |
TOTAL Transmission and Market Operation Plant (Total lines 77 thru 83) |
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85 |
6. General Plant |
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86 |
(389) Land and Land Rights |
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87 |
(390) Structures and Improvements |
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88 |
(391) Office Furniture and Equipment |
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89 |
(392) Transportation Equipment |
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90 |
(393) Stores Equipment |
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91 |
(394) Tools, Shop and Garage Equipment |
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92 |
(395) Laboratory Equipment |
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93 |
(396) Power Operated Equipment |
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94 |
(397) Communication Equipment |
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95 |
(398) Miscellaneous Equipment |
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96 |
SUBTOTAL (Enter Total of lines 86 thru 95) |
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97 |
(399) Other Tangible Property |
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98 |
(399.1) Asset Retirement Costs for General Plant |
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99 |
TOTAL General Plant (Enter Total of lines 96, 97, and 98) |
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100 |
TOTAL (Accounts 101 and 106) |
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101 |
(102) Electric Plant Purchased (See Instr. 8) |
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102 |
(Less) (102) Electric Plant Sold (See Instr. 8) |
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103 |
(103) Experimental Plant Unclassified |
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104 |
TOTAL Electric Plant in Service (Enter Total of lines 100 thru 103) |
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Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
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ELECTRIC PLANT LEASED TO OTHERS (Account 104) |
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| Line No. |
LesseeName Name of Lessee (a) |
IndicationOfAssociatedCompany * (Designation of Associated Company) (b) |
LeaseDescription Description of Property Leased (c) |
CommissionAuthorization Commission Authorization (d) |
ExpirationDateOfLease Expiration Date of Lease (e) |
ElectricPlantLeasedToOthers Balance at End of Year (f) |
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| 47 |
TOTAL |
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Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
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ELECTRIC PLANT HELD FOR FUTURE USE (Account 105) |
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| Line No. |
ElectricPlantHeldForFutureUseDescription Description and Location of Property (a) |
ElectricPlantPropertyClassifiedAsHeldForFutureUseOriginalDate Date Originally Included in This Account (b) |
ElectricPlantPropertyClassifiedAsHeldForFutureUseExpectedUseInServiceDate Date Expected to be used in Utility Service (c) |
ElectricPlantHeldForFutureUse Balance at End of Year (d) |
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| 1 | Land and Rights: | ||||||||
| 2 |
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| 3 | |||||||||
| 21 | Other Property: | ||||||||
| 22 |
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| 47 | TOTAL |
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Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
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CONSTRUCTION WORK IN PROGRESS - - ELECTRIC (Account 107) |
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| Line No. |
ConstructionWorkInProgressProjectDescription Description of Project (a) |
ConstructionWorkInProgress Construction work in progress - Electric (Account 107) (b) |
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| 79 | ||
| 80 | ||
| 81 | ||
| 82 | ||
| 83 | ||
| 84 | ||
| 85 | ||
| 86 | ||
| 87 | ||
| 88 | ||
| 89 | ||
| 90 | ||
| 91 | ||
| 92 | ||
| 93 | ||
| 94 | ||
| 95 | ||
| 96 | ||
| 97 | ||
| 98 | ||
| 99 | ||
| 100 | ||
| 101 | ||
| 102 | ||
| 103 | ||
| 104 | ||
| 105 | ||
| 106 | ||
| 107 | ||
| 108 | ||
| 109 | ||
| 110 | ||
| 111 | ||
| 112 | ||
| 113 | ||
| 114 | ||
| 115 | ||
| 116 | ||
| 117 | ||
| 118 | ||
| 119 | ||
| 120 | ||
| 121 | ||
| 122 | ||
| 123 | ||
| 124 | ||
| 125 | ||
| 126 | ||
| 127 | ||
| 128 | ||
| 129 | ||
| 130 | ||
| 131 | ||
| 132 | ||
| 133 | ||
| 134 | ||
| 135 | ||
| 136 | ||
| 137 | ||
| 138 | ||
| 139 | ||
| 140 | ||
| 141 | ||
| 142 | ||
| 143 | ||
| 144 | ||
| 145 | ||
| 146 | ||
| 147 | ||
| 148 | ||
| 149 | ||
| 150 | ||
| 151 | ||
| 152 | ||
| 153 | ||
| 154 | ||
| 155 | ||
| 156 | ||
| 157 | ||
| 158 | ||
| 159 | ||
| 160 | ||
| 161 | ||
| 162 | ||
| 163 | ||
| 164 | ||
| 165 | ||
| 166 | ||
| 167 | ||
| 168 | ||
| 169 | ||
| 170 | ||
| 171 | ||
| 172 | ||
| 43 |
Total |
|
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
ACCUMULATED PROVISION FOR DEPRECIATION OF ELECTRIC UTILITY PLANT (Account 108) |
|||||
|
|||||
| Line No. |
Item (a) |
Total (c + d + e) (b) |
Electric Plant in Service (c) |
Electric Plant Held for Future Use (d) |
Electric Plant Leased To Others (e) |
| Section A. Balances and Changes During Year | |||||
| 1 |
AccumulatedProvisionForDepreciationOfElectricUtilityPlant
Balance Beginning of Year |
|
|
|
|
| 2 |
Depreciation Provisions for Year, Charged to |
||||
|
3 |
DepreciationExpenseExcludingAdjustments (403) Depreciation Expense |
|
(a) |
||
|
4 |
DepreciationExpenseForAssetRetirementCosts (403.1) Depreciation Expense for Asset Retirement Costs |
|
|
||
|
5 |
ExpensesOfElectricPlantLeasedToOthers (413) Exp. of Elec. Plt. Leas. to Others |
||||
|
6 |
TransportationExpensesClearing Transportation Expenses-Clearing |
||||
|
7 |
OtherClearingAccounts Other Clearing Accounts |
||||
|
8 |
OtherAccounts Other Accounts (Specify, details in footnote): |
||||
| 9.1 | (b) |
||||
| 10 |
DepreciationProvision
TOTAL Deprec. Prov for Year (Enter Total of lines 3 thru 9) |
|
|
||
| 11 |
Net Charges for Plant Retired: |
||||
|
12 |
BookCostOfRetiredPlant Book Cost of Plant Retired |
|
|
||
|
13 |
CostOfRemovalOfPlant Cost of Removal |
|
|
||
|
14 |
SalvageValueOfRetiredPlant Salvage (Credit) |
|
|
||
|
15 |
NetChargesForRetiredPlant TOTAL Net Chrgs. for Plant Ret. (Enter Total of lines 12 thru 14) |
|
|
||
| 16 |
OtherAdjustmentsToAccumulatedDepreciation
Other Debit or Cr. Items (Describe, details in footnote): |
||||
| 17.1 | (c) |
||||
| 18 |
BookCostOfAssetRetirementCosts
Book Cost or Asset Retirement Costs Retired |
||||
| 19 |
AccumulatedProvisionForDepreciationOfElectricUtilityPlant
Balance End of Year (Enter Totals of lines 1, 10, 15, 16, and 18) |
|
|
|
|
| Section B. Balances at End of Year According to Functional Classification | |||||
|
20 |
AccumulatedDepreciationSteamProduction Steam Production |
|
|
|
|
|
21 |
AccumulatedDepreciationNuclearProduction Nuclear Production |
||||
|
22 |
AccumulatedDepreciationHydraulicProductionConventional Hydraulic Production-Conventional |
||||
|
23 |
AccumulatedDepreciationHydraulicProductionPumpedStorage Hydraulic Production-Pumped Storage |
||||
|
24 |
AccumulatedDepreciationOtherProduction Other Production |
|
|
||
|
25 |
AccumulatedDepreciationTransmission Transmission |
|
|
|
|
|
26 |
AccumulatedDepreciationDistribution Distribution |
|
|
||
|
27 |
AccumulatedDepreciationRegionalTransmissionAndMarketOperation Regional Transmission and Market Operation |
||||
|
28 |
AccumulatedDepreciationGeneral General |
|
|
||
| 29 |
AccumulatedProvisionForDepreciationOfElectricUtilityPlant
TOTAL (Enter Total of lines 20 thru 28) |
|
|
|
|
| FOOTNOTE DATA |
| (a) Concept: DepreciationExpenseExcludingAdjustments | ||||||||||||||||||||||||
| (b) Concept: OtherAccounts | ||||||||||||||||||||||||
| (c) Concept: OtherAdjustmentsToAccumulatedDepreciation | ||||||||||||||||||||||||
| ||||||||||||||||||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
INVESTMENTS IN SUBSIDIARY COMPANIES (Account 123.1) |
||||||||
|
||||||||
| Line No. |
DescriptionOfInvestmentsInSubsidiaryCompanies Description of Investment (a) |
DateOfAcquisitionInvestmentsInSubsidiaryCompanies Date Acquired (b) |
DateOfMaturityInvestmentsInSubsidiaryCompanies Date of Maturity (c) |
InvestmentInSubsidiaryCompanies Amount of Investment at Beginning of Year (d) |
EquityInEarningsOfSubsidiaryCompanies Equity in Subsidiary Earnings of Year (e) |
InterestAndDividendRevenueFromInvestments Revenues for Year (f) |
InvestmentInSubsidiaryCompanies Amount of Investment at End of Year (g) |
InvestmentGainLossOnDisplosal Gain or Loss from Investment Disposed of (h) |
| 1 | ||||||||
| 2 | ||||||||
| 3 | ||||||||
| 4 | ||||||||
| 5 | ||||||||
| 6 | ||||||||
| 7 | ||||||||
| 8 | ||||||||
| 42 |
Total Cost of Account 123.1 $ |
Total |
|
|
|
|
||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
MATERIALS AND SUPPLIES |
||||
|
||||
| Line No. |
Account (a) |
Balance Beginning of Year (b) |
Balance End of Year (c) |
Department or Departments which Use Material (d) |
| 1 |
Fuel Stock (Account 151) |
|
|
|
| 2 |
Fuel Stock Expenses Undistributed (Account 152) |
|||
| 3 |
Residuals and Extracted Products (Account 153) |
|||
| 4 |
Plant Materials and Operating Supplies (Account 154) |
|||
| 5 |
Assigned to - Construction (Estimated) |
(a) |
(b) |
|
| 6 |
Assigned to - Operations and Maintenance |
|||
| 7 |
Production Plant (Estimated) |
|
|
|
| 8 |
Transmission Plant (Estimated) |
|
|
|
| 9 |
Distribution Plant (Estimated) |
|
|
|
| 10 |
Regional Transmission and Market Operation Plant (Estimated) |
|||
| 11 |
Assigned to - Other (provide details in footnote) |
|||
| 12 |
TOTAL Account 154 (Enter Total of lines 5 thru 11) |
|
|
|
| 13 |
Merchandise (Account 155) |
|||
| 14 |
Other Materials and Supplies (Account 156) |
|||
| 15 |
Nuclear Materials Held for Sale (Account 157) (Not
applic to Gas Util) |
|||
| 16 |
Stores Expense Undistributed (Account 163) |
|
|
|
| 17 | ||||
| 18 | ||||
| 19 | ||||
| 20 |
TOTAL Materials and Supplies |
|
|
|
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: PlantMaterialsAndOperatingSuppliesConstruction | ||||||||||||||||||||||||||||||||||||||||||
| ||||||||||||||||||||||||||||||||||||||||||
| (b) Concept: PlantMaterialsAndOperatingSuppliesConstruction | ||||||||||||||||||||||||||||||||||||||||||
| ||||||||||||||||||||||||||||||||||||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
Allowances (Accounts 158.1 and 158.2) |
|||||||||||||
|
|||||||||||||
| Current Year | Year One | Year Two | Year Three | Future Years | Totals | ||||||||
| Line No. |
SO2 Allowances Inventory (Account 158.1) (a) |
No. (b) |
Amt. (c) |
No. (d) |
Amt. (e) |
No. (f) |
Amt. (g) |
No. (h) |
Amt. (i) |
No. (j) |
Amt. (k) |
No. (l) |
Amt. (m) |
1 |
Balance-Beginning of Year |
||||||||||||
2 |
|||||||||||||
3 |
Acquired During Year: |
||||||||||||
4 |
Issued (Less Withheld Allow) |
(a) |
|||||||||||
5 |
Returned by EPA |
||||||||||||
6 |
|||||||||||||
7 |
|||||||||||||
8 |
|||||||||||||
9 |
|||||||||||||
10 |
|||||||||||||
11 |
|||||||||||||
12 |
|||||||||||||
13 |
|||||||||||||
14 |
|||||||||||||
15 |
Total |
||||||||||||
16 |
|||||||||||||
17 |
Relinquished During Year: |
||||||||||||
18 |
Charges to Account 509 |
||||||||||||
19 |
Other: |
||||||||||||
20 |
Allowances Used |
||||||||||||
20.1 |
|||||||||||||
21 |
Cost of Sales/Transfers: |
||||||||||||
22 |
|||||||||||||
23 |
|||||||||||||
24 |
|||||||||||||
25 |
|||||||||||||
26 |
|||||||||||||
27 |
|||||||||||||
28 |
Total |
||||||||||||
29 |
Balance-End of Year |
||||||||||||
30 |
|||||||||||||
31 |
Sales: |
||||||||||||
32 |
Net Sales Proceeds(Assoc. Co.) |
||||||||||||
33 |
Net Sales Proceeds (Other) |
||||||||||||
34 |
Gains |
||||||||||||
35 |
Losses |
||||||||||||
Allowances Withheld (Acct 158.2) |
|||||||||||||
36 |
Balance-Beginning of Year |
||||||||||||
37 |
Add: Withheld by EPA |
||||||||||||
38 |
Deduct: Returned by EPA |
||||||||||||
39 |
Cost of Sales |
||||||||||||
40 |
Balance-End of Year |
||||||||||||
41 |
|||||||||||||
42 |
Sales |
||||||||||||
43 |
Net Sales Proceeds (Assoc. Co.) |
||||||||||||
44 |
Net Sales Proceeds (Other) |
||||||||||||
45 |
Gains |
||||||||||||
46 |
Losses |
||||||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: AllowancesIssuedLessWithheldAllowancesNumber |
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
Allowances (Accounts 158.1 and 158.2) |
|||||||||||||
|
|||||||||||||
| Current Year | Year One | Year Two | Year Three | Future Years | Totals | ||||||||
| Line No. |
NOx Allowances Inventory (Account 158.1) (a) |
No. (b) |
Amt. (c) |
No. (d) |
Amt. (e) |
No. (f) |
Amt. (g) |
No. (h) |
Amt. (i) |
No. (j) |
Amt. (k) |
No. (l) |
Amt. (m) |
1 |
Balance-Beginning of Year |
||||||||||||
2 |
|||||||||||||
3 |
Acquired During Year: |
||||||||||||
4 |
Issued (Less Withheld Allow) |
(a) |
|||||||||||
5 |
Returned by EPA |
||||||||||||
6 |
|||||||||||||
7 |
|||||||||||||
8 |
|||||||||||||
9 |
|||||||||||||
10 |
|||||||||||||
11 |
|||||||||||||
12 |
|||||||||||||
13 |
|||||||||||||
14 |
|||||||||||||
15 |
Total |
||||||||||||
16 |
|||||||||||||
17 |
Relinquished During Year: |
||||||||||||
18 |
Charges to Account 509 |
||||||||||||
19 |
Other: |
||||||||||||
20 |
Allowances Used |
||||||||||||
20.1 |
|||||||||||||
21 |
Cost of Sales/Transfers: |
||||||||||||
22 |
|||||||||||||
23 |
|||||||||||||
24 |
|||||||||||||
25 |
|||||||||||||
26 |
|||||||||||||
27 |
|||||||||||||
28 |
Total |
||||||||||||
29 |
Balance-End of Year |
||||||||||||
30 |
|||||||||||||
31 |
Sales: |
||||||||||||
32 |
Net Sales Proceeds(Assoc. Co.) |
||||||||||||
33 |
Net Sales Proceeds (Other) |
||||||||||||
34 |
Gains |
||||||||||||
35 |
Losses |
||||||||||||
Allowances Withheld (Acct 158.2) |
|||||||||||||
36 |
Balance-Beginning of Year |
||||||||||||
37 |
Add: Withheld by EPA |
||||||||||||
38 |
Deduct: Returned by EPA |
||||||||||||
39 |
Cost of Sales |
||||||||||||
40 |
Balance-End of Year |
||||||||||||
41 |
|||||||||||||
42 |
Sales |
||||||||||||
43 |
Net Sales Proceeds (Assoc. Co.) |
||||||||||||
44 |
Net Sales Proceeds (Other) |
||||||||||||
45 |
Gains |
||||||||||||
46 |
Losses |
||||||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: AllowancesIssuedLessWithheldAllowancesNumber |
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
EXTRAORDINARY PROPERTY LOSSES (Account 182.1) |
||||||
| WRITTEN OFF DURING YEAR | ||||||
| Line No. |
DescriptionOfExtraordinaryPropertyLoss Description of Extraordinary Loss [Include in the description the date of Commission Authorization to use Acc 182.1 and period of amortization (mo, yr to mo, yr).] (a) |
ExtraordinaryPropertyLossesNotYetRecognized Total Amount of Loss (b) |
ExtraordinaryPropertyLossesRecognized Losses Recognized During Year (c) |
ExtraordinaryPropertyLossesWrittenOffAccountCharged Account Charged (d) |
ExtraordinaryPropertyLossesWrittenOff Amount (e) |
ExtraordinaryPropertyLosses Balance at End of Year (f) |
| 1 | ||||||
| 2 | ||||||
| 3 | ||||||
| 4 | ||||||
| 5 | ||||||
| 6 | ||||||
| 7 | ||||||
| 8 | ||||||
| 9 | ||||||
| 10 | ||||||
| 11 | ||||||
| 12 | ||||||
| 13 | ||||||
| 14 | ||||||
| 15 | ||||||
| 16 | ||||||
| 17 | ||||||
| 18 | ||||||
| 19 | ||||||
| 20 | ||||||
| 21 | ||||||
| 22 | ||||||
| 23 | ||||||
| 24 | ||||||
| 25 | ||||||
| 26 | ||||||
| 27 | ||||||
| 28 | ||||||
| 20 | TOTAL | |||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
UNRECOVERED PLANT AND REGULATORY STUDY COSTS (182.2) |
||||||
| WRITTEN OFF DURING YEAR | ||||||
| Line No. |
DescriptionOfUnrecoveredPlantAndRegulatoryStudyCosts Description of Unrecovered Plant and Regulatory Study Costs [Include in the description of costs, the date of COmmission Authorization to use Acc 182.2 and period of amortization (mo, yr to mo, yr)] (a) |
UnrecoveredPlantAndRegulatoryStudyCostsNotYetRecognized Total Amount of Charges (b) |
UnrecoveredPlantAndRegulatoryStudyCostsRecognized Costs Recognized During Year (c) |
UnrecoveredPlantAndRegulatoryStudyCostsWrittenOffAccountCharged Account Charged (d) |
UnrecoveredPlantAndRegulatoryStudyCostsWrittenOff Amount (e) |
UnrecoveredPlantAndRegulatoryStudyCosts Balance at End of Year (f) |
| 21 | ||||||
| 22 | ||||||
| 23 | ||||||
| 24 | ||||||
| 25 | ||||||
| 26 | ||||||
| 27 | ||||||
| 28 | ||||||
| 29 | ||||||
| 30 | ||||||
| 31 | ||||||
| 32 | ||||||
| 33 | ||||||
| 34 | ||||||
| 35 | ||||||
| 36 | ||||||
| 37 | ||||||
| 38 | ||||||
| 39 | ||||||
| 40 | ||||||
| 41 | ||||||
| 42 | ||||||
| 43 | ||||||
| 44 | ||||||
| 45 | ||||||
| 46 | ||||||
| 47 | ||||||
| 48 | ||||||
| 49 |
TOTAL |
|||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
Transmission Service and Generation Interconnection Study Costs |
|||||
|
|||||
| Line No. |
DescriptionOfStudyPerformed Description (a) |
StudyCostsIncurred Costs Incurred During Period (b) |
StudyCostsAccountCharged Account Charged (c) |
StudyCostsReimbursements Reimbursements Received During the Period (d) |
StudyCostsAccountReimbursed Account Credited With Reimbursement (e) |
| 1 |
Transmission Studies |
||||
| 2 | |||||
| 3 | |||||
| 4 | |||||
| 5 | |||||
| 6 | |||||
| 7 | |||||
| 8 | |||||
| 9 | |||||
| 10 | |||||
| 11 | |||||
| 12 | |||||
| 13 | |||||
| 14 | |||||
| 15 | |||||
| 16 | |||||
| 17 | |||||
| 18 | |||||
| 19 | |||||
| 20 |
Total |
||||
| 21 |
Generation Studies |
||||
| 22 | |||||
| 23 | |||||
| 24 | |||||
| 25 | |||||
| 26 | |||||
| 27 | |||||
| 28 | |||||
| 29 | |||||
| 30 | |||||
| 31 | |||||
| 32 | |||||
| 33 | |||||
| 34 | |||||
| 35 | |||||
| 36 | |||||
| 37 | |||||
| 38 | |||||
| 39 |
Total |
||||
| 40 | Grand Total | ||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
OTHER REGULATORY ASSETS (Account 182.3) |
||||||
|
||||||
| CREDITS | ||||||
| Line No. |
DescriptionAndPurposeOfOtherRegulatoryAssets Description and Purpose of Other Regulatory Assets (a) |
OtherRegulatoryAssets Balance at Beginning of Current Quarter/Year (b) |
IncreaseDecreaseInOtherRegulatoryAssets Debits (c) |
OtherRegulatoryAssetsWrittenOffAccountCharged Written off During Quarter/Year Account Charged (d) |
OtherRegulatoryAssetsWrittenOffRecovered Written off During the Period Amount (e) |
OtherRegulatoryAssets Balance at end of Current Quarter/Year (f) |
| 1 | ||||||
| 2 | ||||||
| 3 | ||||||
| 4 | ||||||
| 5 | ||||||
| 6 | ||||||
| 7 | ||||||
| 8 | ||||||
| 9 | ||||||
| 10 | ||||||
| 11 | ||||||
| 12 | ||||||
| 13 | ||||||
| 14 | ||||||
| 15 | ||||||
| 16 | ||||||
| 17 | ||||||
| 18 | ||||||
| 19 | ||||||
| 20 | ||||||
| 21 | ||||||
| 22 | ||||||
| 23 | ||||||
| 24 | ||||||
| 25 | ||||||
| 26 | ||||||
| 27 | ||||||
| 44 |
TOTAL |
|
|
|
|
|
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
MISCELLANEOUS DEFFERED DEBITS (Account 186) |
||||||
|
||||||
| CREDITS | ||||||
| Line No. |
Description of Miscellaneous Deferred Debits (a) |
Balance at Beginning of Year (b) |
Debits (c) |
Credits Account Charged (d) |
Credits Amount (e) |
Balance at End of Year (f) |
| 1 |
|
|
|
|
||
| 2 |
|
|
|
|
||
| 3 |
|
|
|
|
||
| 4 |
|
|
|
|
|
|
| 47 |
Miscellaneous Work in Progress |
|||||
| 48 |
Deferred Regulatory Comm. Expenses (See pages 350 - 351) |
|||||
| 49 |
TOTAL |
|
|
|||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
ACCUMULATED DEFERRED INCOME TAXES (Account 190) |
|||
|
|||
| Line No. |
DescriptionOfAccumulatedDeferredIncomeTax Description and Location (a) |
AccumulatedDeferredIncomeTaxes Balance at Beginning of Year (b) |
AccumulatedDeferredIncomeTaxes Balance at End of Year (c) |
| 1 |
Electric |
||
| 2 |
(a) |
|
|
| 7 |
Other |
||
| 8 |
TOTAL Electric (Enter Total of lines 2 thru 7) |
|
|
| 9 |
Gas |
||
| 15 |
Other |
||
| 16 |
TOTAL Gas (Enter Total of lines 10 thru 15) |
||
|
17.1 |
|
||
| 17 |
Other (Specify) |
||
| 18 |
TOTAL (Acct 190) (Total of lines 8, 16 and 17) |
|
|
| Notes |
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: DescriptionOfAccumulatedDeferredIncomeTax | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
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Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
CAPITAL STOCKS (Account 201 and 204) |
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| Line No. |
Class and Series of Stock and Name of Stock Series (a) |
Number of Shares Authorized by Charter (b) |
Par or Stated Value per Share (c) |
Call Price at End of Year (d) |
Outstanding per Bal. Sheet (Total amount outstanding without reduction for amounts held by respondent) Shares (e) |
Outstanding per Bal. Sheet (Total amount outstanding without reduction for amounts held by respondent) Amount (f) |
Held by Respondent As Reacquired Stock (Acct 217) Shares (g) |
Held by Respondent As Reacquired Stock (Acct 217) Cost (h) |
Held by Respondent In Sinking and Other Funds Shares (i) |
Held by Respondent In Sinking and Other Funds Amount (j) |
| 1 |
Common Stock (Account 201) |
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| 2 | ||||||||||
| 3 | ||||||||||
| 4 | ||||||||||
|
5 |
Total |
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|
6 |
Preferred Stock (Account 204) |
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| 7 | ||||||||||
| 8 | ||||||||||
| 9 | ||||||||||
|
10 |
Total |
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| 1 |
Capital Stock (Accounts 201 and 204) - Data Conversion |
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| 2 | ||||||||||
| 3 | ||||||||||
| 4 | ||||||||||
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5 |
Total |
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Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
Other Paid-in Capital |
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|
1. Report below the balance at the end of the year and the information specified below for the respective other paid-in capital accounts. Provide a subheading for each account and show a total for the account, as well as a total of all accounts for reconciliation with the balance sheet, page 112. Explain changes made in any account during the year and give the accounting entries effecting such change.
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| Line No. |
Item (a) |
Amount (b) |
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|
1 |
DonationsReceivedFromStockholdersAbstract Donations Received from Stockholders (Account 208) |
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2 |
DonationsReceivedFromStockholders Beginning Balance Amount |
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3.1 |
IncreasesDecreasesFromSalesOfDonationsReceivedFromStockholders |
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4 |
DonationsReceivedFromStockholders Ending Balance Amount |
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5 |
ReductionInParOrStatedValueOfCapitalStockAbstract Reduction in Par or Stated Value of Capital Stock (Account 209) |
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6 |
ReductionInParOrStatedValueOfCapitalStock Beginning Balance Amount |
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7.1 |
IncreasesDecreasesDueToReductionsInParOrStatedValueOfCapitalStock |
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8 |
ReductionInParOrStatedValueOfCapitalStock Ending Balance Amount |
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9 |
GainOrResaleOrCancellationOfReacquiredCapitalStockAbstract Gain or Resale or Cancellation of Reacquired Capital Stock (Account 210) |
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10 |
GainOnResaleOrCancellationOfReacquiredCapitalStock Beginning Balance Amount |
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|
11.1 |
IncreasesDecreasesFromGainOrResaleOrCancellationOfReacquiredCapitalStock |
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|
12 |
GainOnResaleOrCancellationOfReacquiredCapitalStock Ending Balance Amount |
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13 |
MiscellaneousPaidInCapitalAbstract Miscellaneous Paid-In Capital (Account 211) |
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14 |
MiscellaneousPaidInCapital Beginning Balance Amount |
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|
15.1 |
IncreasesDecreasesDueToMiscellaneousPaidInCapital |
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16 |
MiscellaneousPaidInCapital Ending Balance Amount |
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17 |
OtherPaidInCapitalAbstract Historical Data - Other Paid in Capital |
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18 |
OtherPaidInCapitalDetail Beginning Balance Amount |
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|
19.1 |
IncreasesDecreasesInOtherPaidInCapital |
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20 |
OtherPaidInCapitalDetail Ending Balance Amount |
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|
40 |
OtherPaidInCapital Total |
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Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
CAPITAL STOCK EXPENSE (Account 214) |
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| Line No. |
NameOfClassAndSeriesOfStock Class and Series of Stock (a) |
CapitalStockExpense Balance at End of Year (b) |
| 1 | ||
| 2 | ||
| 3 | ||
| 4 | ||
| 5 | ||
| 6 | ||
| 7 | ||
| 8 | ||
| 9 | ||
| 10 | ||
| 11 | ||
| 12 | ||
| 13 | ||
| 14 | ||
| 15 | ||
| 16 | ||
| 17 | ||
| 18 | ||
| 19 | ||
| 20 | ||
| 21 | ||
| 22 |
TOTAL |
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|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
LONG-TERM DEBT (Account 221, 222, 223 and 224) |
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| Line No. |
ClassAndSeriesOfObligationCouponRateDescription Class and Series of Obligation, Coupon Rate (For new issue, give commission Authorization numbers and dates) (a) |
RelatedAccountNumber Related Account Number (b) |
Principal Amount of Debt Issued (c) |
LongTermDebtIssuanceExpensePremiumOrDiscount Total Expense, Premium or Discount (d) |
LongTermDebtIssuanceExpenses Total Expense (e) |
LongTermDebtPremium Total Premium (f) |
LongTermDebtDiscount Total Discount (g) |
NominalDateOfIssue Nominal Date of Issue (h) |
DateOfMaturity Date of Maturity (i) |
AmortizationPeriodStartDate AMORTIZATION PERIOD Date From (j) |
AmortizationPeriodEndDate AMORTIZATION PERIOD Date To (k) |
Outstanding (Total amount outstanding without reduction for amounts held by respondent) (l) |
Interest for Year Amount (m) |
| 1 |
Bonds (Account 221) |
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| 2 | (a) |
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| 3 | |||||||||||||
| 4 | |||||||||||||
| 5 | |||||||||||||
| 6 | |||||||||||||
| 7 | |||||||||||||
| 8 | |||||||||||||
| 9 | |||||||||||||
| 10 | |||||||||||||
| 11 | |||||||||||||
| 12 | |||||||||||||
| 13 | |||||||||||||
|
14 |
Subtotal |
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15 |
Reacquired Bonds (Account 222) |
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| 16 | |||||||||||||
| 17 | |||||||||||||
| 18 | |||||||||||||
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19 |
Subtotal | ||||||||||||
20 |
Advances from Associated Companies (Account 223) |
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| 21 | |||||||||||||
| 22 | |||||||||||||
| 23 | |||||||||||||
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24 |
Subtotal | ||||||||||||
25 |
Other Long Term Debt (Account 224) |
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| 26 | (b) |
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| 27 | |||||||||||||
|
28 |
Subtotal |
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| 33 | TOTAL |
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|
(c) |
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|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: Bonds |
| (b) Concept: OtherLongTermDebt |
| (c) Concept: InterestExpenseOnLongTermDebtIssued |
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
RECONCILIATION OF REPORTED NET INCOME WITH TAXABLE INCOME FOR FEDERAL INCOME TAXES |
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||
| Line No. |
Particulars (Details) (a) |
Amount (b) |
| 1 |
Net Income for the Year (Page 117) |
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| 2 |
Reconciling Items for the Year |
|
| 3 | ||
| 4 |
Taxable Income Not Reported on Books |
|
| 5 | (a) |
|
| 9 |
Deductions Recorded on Books Not Deducted for Return |
|
| 10 | (b) |
|
| 14 |
Income Recorded on Books Not Included in Return |
|
| 15 | (c) |
|
| 19 |
Deductions on Return Not Charged Against Book Income |
|
| 20 | (d) |
|
| 21 | (e) |
|
| 27 |
Federal Tax Net Income |
|
| 28 |
Show Computation of Tax: |
|
| 29 | ||
| 30 | (f) |
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|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: TaxableIncomeNotReportedOnBooksDescription | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| (b) Concept: DeductionsRecordedOnBooksNotDeductedForReturnDescription | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| (c) Concept: IncomeRecordedOnBooksNotIncludedInReturnDescription | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| (d) Concept: DeductionsOnReturnNotChargedAgainstBookIncomeDescription | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| (e) Concept: DeductionsOnReturnNotChargedAgainstBookIncomeDescription | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| (f) Concept: ComputationOfTaxDescription | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
The Respondent intends to join in the filing of a consolidated Federal Income Tax Return by Entergy Corporation and Subsidiary Companies for the year ended 2023. The estimated consolidated tax allocable under Entergy and Subsidiary Companies Intercompany Income Tax Allocation Agreement based on the provisions of Securities and Exchange Commission Rule 45(c) follows:
| ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
TAXES ACCRUED, PREPAID AND CHARGES DURING YEAR |
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| BALANCE AT BEGINNING OF YEAR | BALANCE AT END OF YEAR | DISTRIBUTION OF TAXES CHARGED | |||||||||||||
| Line No. |
DescriptionOfTaxesAccruedPrepaidAndCharged Kind of Tax (See Instruction 5) (a) |
TypeOfTax Type of Tax (b) |
TaxJurisdiction State (c) |
TaxYear Tax Year (d) |
TaxesAccrued Taxes Accrued (Account 236) (e) |
PrepaidTaxes Prepaid Taxes (Include in Account 165) (f) |
TaxesCharged Taxes Charged During Year (g) |
TaxesPaid Taxes Paid During Year (h) |
TaxAdjustments Adjustments (i) |
TaxesAccrued Taxes Accrued (Account 236) (j) |
PrepaidTaxes Prepaid Taxes (Included in Account 165) (k) |
TaxesAccruedPrepaidAndCharged Electric (Account 408.1, 409.1) (l) |
IncomeTaxesExtraordinaryItems Extraordinary Items (Account 409.3) (m) |
AdjustmentsToRetainedEarnings Adjustment to Ret. Earnings (Account 439) (n) |
TaxesIncurredOther Other (o) |
| 1 | |||||||||||||||
| 2 | |||||||||||||||
| 3 | |||||||||||||||
| 4 | |||||||||||||||
| 5 | Subtotal Federal Tax |
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| 6 | |||||||||||||||
| 7 | |||||||||||||||
| 8 | Subtotal State Tax |
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| 9 | |||||||||||||||
| 10 | Subtotal Local Tax |
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| 11 | |||||||||||||||
| 12 | |||||||||||||||
| 13 | Subtotal Other Tax |
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| 14 | Subtotal Property Tax |
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| 15 | Subtotal Real Estate Tax |
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| 16 | |||||||||||||||
| 17 | Subtotal Unemployment Tax |
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| 18 | |||||||||||||||
| 19 | Subtotal Sales And Use Tax |
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| 20 | |||||||||||||||
| 21 | Subtotal Income Tax |
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| 22 | |||||||||||||||
| 23 | Subtotal Excise Tax |
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| 24 | Subtotal Fuel Tax |
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| 25 | Subtotal Federal Insurance Tax |
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| 26 | |||||||||||||||
| 27 | |||||||||||||||
| 28 | Subtotal Franchise Tax |
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| 29 | |||||||||||||||
| 30 | Subtotal Miscellaneous Other Tax |
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| 31 | Subtotal Other Federal Tax |
||||||||||||||
| 32 | |||||||||||||||
| 33 | Subtotal Other State Tax |
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| 34 | Subtotal Other Property Tax |
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| 35 | Subtotal Other Use Tax |
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| 36 | |||||||||||||||
| 37 | |||||||||||||||
| 38 | Subtotal Other Advalorem Tax |
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| 39 | Subtotal Other License And Fees Tax |
||||||||||||||
| 40 | Subtotal Payroll Tax |
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| 41 | Subtotal Advalorem Tax |
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| 42 | |||||||||||||||
| 43 | Subtotal Other Allocated Tax |
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| 44 | Subtotal Severance Tax |
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| 45 | Subtotal Penalty Tax |
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| 46 | Subtotal Other Taxes And Fees |
||||||||||||||
| 40 |
TOTAL |
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|
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|
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|
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|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
ACCUMULATED DEFERRED INVESTMENT TAX CREDITS (Account 255) |
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|
Report below information applicable to Account 255. Where appropriate, segregate the balances and transactions by utility and nonutility operations. Explain by footnote any correction adjustments to the account balance shown in column (g). Include in column (i) the average period over which the tax credits are amortized. |
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| Deferred for Year | Allocations to Current Year's Income | ||||||||||
| Line No. |
Account Subdivisions (a) |
Balance at Beginning of Year (b) |
Account No. (c) |
Amount (d) |
Account No. (e) |
Amount (f) |
Adjustments (g) |
Balance at End of Year (h) |
Average Period of Allocation to Income (i) |
ADJUSTMENT EXPLANATION (j) |
|
| 1 | Electric Utility |
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| 2 |
|
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| 3 |
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| 4 |
|
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| 5 |
|
(a) |
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| 8 |
TOTAL Electric (Enter Total of lines 2 thru 7) |
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|
|||||||
| 9 | Other (List separately and show 3%, 4%, 7%, 10% and TOTAL) |
||||||||||
| 10 | |||||||||||
| 11 | |||||||||||
| 47 | OTHER TOTAL |
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|
|
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|
|||||
| 48 | GRAND TOTAL |
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Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: AccumulatedDeferredInvestmentTaxCreditsAveragePeriodOfAllocationToIncome |
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
OTHER DEFERRED CREDITS (Account 253) |
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| DEBITS | ||||||
| Line No. |
Description and Other Deferred Credits (a) |
Balance at Beginning of Year (b) |
Contra Account (c) |
Amount (d) |
Credits (e) |
Balance at End of Year (f) |
| 1 | ||||||
| 2 | ||||||
| 3 | ||||||
| 4 | ||||||
| 5 | ||||||
| 47 |
TOTAL |
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|
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|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
ACCUMULATED DEFERRED INCOME TAXES - ACCELERATED AMORTIZATION PROPERTY (Account 281) |
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| CHANGES DURING YEAR | ADJUSTMENTS | |||||||||||
| Debits | Credits | |||||||||||
| Line No. |
Account (a) |
Balance at Beginning of Year (b) |
Amounts Debited to Account 410.1 (c) |
Amounts Credited to Account 411.1 (d) |
Amounts Debited to Account 410.2 (e) |
Amounts Credited to Account 411.2 (f) |
Account Credited (g) |
Amount (h) |
Account Debited (i) |
Amount (j) |
Balance at End of Year (k) |
|
1 |
Accelerated Amortization (Account 281) |
|||||||||||
2 |
Electric |
|||||||||||
3 |
Defense Facilities |
|||||||||||
4 |
Pollution Control Facilities |
|||||||||||
5 |
Other |
|||||||||||
5.1 |
|
|||||||||||
8 |
TOTAL Electric (Enter Total of lines 3 thru 7) |
|||||||||||
9 |
Gas |
|||||||||||
10 |
Defense Facilities |
|||||||||||
11 |
Pollution Control Facilities |
|||||||||||
12 |
Other |
|||||||||||
12.1 |
|
|||||||||||
15 |
TOTAL Gas (Enter Total of lines 10 thru 14) |
|||||||||||
16 |
Other |
|||||||||||
16.1 |
Other |
|||||||||||
16.2 |
Other |
|||||||||||
17 |
TOTAL (Acct 281) (Total of 8, 15 and 16) |
|||||||||||
| 18 |
Classification of TOTAL |
|||||||||||
| 19 |
Federal Income Tax |
|||||||||||
| 20 |
State Income Tax |
|||||||||||
| 21 |
Local Income Tax |
|||||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
ACCUMULATED DEFERRED INCOME TAXES - OTHER PROPERTY (Account 282) |
||||||||||||
|
||||||||||||
| CHANGES DURING YEAR | ADJUSTMENTS | |||||||||||
| Debits | Credits | |||||||||||
| Line No. |
Account (a) |
Balance at Beginning of Year (b) |
Amounts Debited to Account 410.1 (c) |
Amounts Credited to Account 411.1 (d) |
Amounts Debited to Account 410.2 (e) |
Amounts Credited to Account 411.2 (f) |
Account Credited (g) |
Amount (h) |
Account Debited (i) |
Amount (j) |
Balance at End of Year (k) |
|
| 1 | Account 282 | |||||||||||
2 |
Electric |
|||||||||||
3 |
Gas |
|||||||||||
4 |
Other (Specify) |
|||||||||||
5 |
Total (Total of lines 2 thru 4) |
|||||||||||
| 6 | ||||||||||||
| 7 | ||||||||||||
| 8 | ||||||||||||
| 9 |
TOTAL Account 282 (Total of Lines 5 thru 8) |
|
|
|
|
|
||||||
| 10 |
Classification of TOTAL |
|||||||||||
| 11 |
Federal Income Tax |
|
|
|
|
|
|
|||||
| 12 |
State Income Tax |
|
|
|
|
|
|
|||||
| 13 |
Local Income Tax |
|||||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
ACCUMULATED DEFERRED INCOME TAXES - OTHER (Account 283) |
|||||||||||
|
|||||||||||
| CHANGES DURING YEAR | ADJUSTMENTS | ||||||||||
| Debits | Credits | ||||||||||
| Line No. |
Account (a) |
Balance at Beginning of Year (b) |
Amounts Debited to Account 410.1 (c) |
Amounts Credited to Account 411.1 (d) |
Amounts Debited to Account 410.2 (e) |
Amounts Credited to Account 411.2 (f) |
Account Credited (g) |
Amount (h) |
Account Debited (i) |
Amount (j) |
Balance at End of Year (k) |
| 1 | Account 283 | ||||||||||
| 2 |
Electric |
||||||||||
| 3 |
(a) |
|
|
|
|
|
|
|
|
||
| 9 | TOTAL Electric (Total of lines 3 thru 8) |
|
|
|
|
|
|
||||
| 10 |
Gas |
||||||||||
| 11 | |||||||||||
| 12 | |||||||||||
| 13 | |||||||||||
| 14 | |||||||||||
| 15 | |||||||||||
| 16 | |||||||||||
| 17 | TOTAL Gas (Total of lines 11 thru 16) | ||||||||||
| 18 | TOTAL Other | ||||||||||
| 19 | TOTAL (Acct 283) (Enter Total of lines 9, 17 and 18) |
|
|
|
|
|
|
||||
| 20 |
Classification of TOTAL |
||||||||||
| 21 |
Federal Income Tax |
|
|
|
|
|
|
|
|
||
| 22 |
State Income Tax |
|
|
|
|
|
|
|
|
||
| 23 |
Local Income Tax |
||||||||||
|
NOTES |
|||||||||||
| FOOTNOTE DATA |
| (a) Concept: DescriptionOfAccumulatedDeferredIncomeTaxOther | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
OTHER REGULATORY LIABILITIES (Account 254) |
||||||
|
||||||
| DEBITS | ||||||
| Line No. |
Description and Purpose of Other Regulatory Liabilities (a) |
Balance at Beginning of Current Quarter/Year (b) |
Account Credited (c) |
Amount (d) |
Credits (e) |
Balance at End of Current Quarter/Year (f) |
| 1 |
|
|
|
|
|
|
| 2 |
|
|
|
|
||
| 3 |
|
|
|
|
||
| 4 |
|
|
|
|||
| 5 |
|
|
|
|
||
| 6 |
|
|
|
|
||
| 7 |
|
|
|
|
|
|
| 8 |
|
|
|
|
||
| 9 |
|
|
|
|||
| 10 |
|
|
|
|
|
|
| 41 | TOTAL |
|
|
|
|
|
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
Electric Operating Revenues |
|||||||
|
|||||||
| Line No. |
Title of Account (a) |
Operating Revenues Year to Date Quarterly/Annual (b) |
Operating Revenues Previous year (no Quarterly) (c) |
MEGAWATT HOURS SOLD Year to Date Quarterly/Annual (d) |
MEGAWATT HOURS SOLD Amount Previous year (no Quarterly) (e) |
AVG.NO. CUSTOMERS PER MONTH Current Year (no Quarterly) (f) |
AVG.NO. CUSTOMERS PER MONTH Previous Year (no Quarterly) (g) |
|
1 |
SalesOfElectricityHeadingAbstract Sales of Electricity |
||||||
|
2 |
ResidentialSalesAbstract (440) Residential Sales |
|
|
|
|
|
|
|
3 |
CommercialAndIndustrialSalesAbstract (442) Commercial and Industrial Sales |
||||||
|
4 |
CommercialSalesAbstract Small (or Comm.) (See Instr. 4) |
(a) |
(d) |
|
|
|
|
|
5 |
IndustrialSalesAbstract Large (or Ind.) (See Instr. 4) |
|
|
|
|
|
|
|
6 |
PublicStreetAndHighwayLightingAbstract (444) Public Street and Highway Lighting |
|
|
|
|
|
|
|
7 |
OtherSalesToPublicAuthoritiesAbstract (445) Other Sales to Public Authorities |
|
|
|
|
|
|
|
8 |
SalesToRailroadsAndRailwaysAbstract (446) Sales to Railroads and Railways |
||||||
|
9 |
InterdepartmentalSalesAbstract (448) Interdepartmental Sales |
||||||
|
10 |
SalesToUltimateConsumersAbstract TOTAL Sales to Ultimate Consumers |
|
|
|
|
|
|
|
11 |
SalesForResaleAbstract (447) Sales for Resale |
|
|
|
|
||
|
12 |
SalesOfElectricityAbstract TOTAL Sales of Electricity |
|
|
|
|
|
|
|
13 |
ProvisionForRateRefundsAbstract (Less) (449.1) Provision for Rate Refunds |
||||||
|
14 |
RevenuesNetOfProvisionForRefundsAbstract TOTAL Revenues Before Prov. for Refunds |
|
|
|
|
|
|
|
15 |
OtherOperatingRevenuesAbstract Other Operating Revenues |
||||||
|
16 |
ForfeitedDiscounts (450) Forfeited Discounts |
|
|
||||
|
17 |
MiscellaneousServiceRevenues (451) Miscellaneous Service Revenues |
(b) |
(e) |
||||
|
18 |
SalesOfWaterAndWaterPower (453) Sales of Water and Water Power |
||||||
|
19 |
RentFromElectricProperty (454) Rent from Electric Property |
|
|
||||
|
20 |
InterdepartmentalRents (455) Interdepartmental Rents |
||||||
|
21 |
OtherElectricRevenue (456) Other Electric Revenues |
(c) |
(f) |
||||
|
22 |
RevenuesFromTransmissionOfElectricityOfOthers (456.1) Revenues from Transmission of Electricity of Others |
|
|
||||
|
23 |
RegionalTransmissionServiceRevenues (457.1) Regional Control Service Revenues |
|
|
||||
|
24 |
MiscellaneousRevenue (457.2) Miscellaneous Revenues |
||||||
|
25 |
OtherMiscellaneousOperatingRevenues Other Miscellaneous Operating Revenues |
||||||
|
26 |
OtherOperatingRevenues TOTAL Other Operating Revenues |
|
|
||||
|
27 |
ElectricOperatingRevenues TOTAL Electric Operating Revenues |
|
|
||||
| Line12, column (b) includes $ of unbilled revenues. | |||||||
| Line12, column (d) includes MWH relating to unbilled revenues | |||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: SmallOrCommercialSalesElectricOperatingRevenue | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| (b) Concept: MiscellaneousServiceRevenues | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| (c) Concept: OtherElectricRevenue | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| (d) Concept: SmallOrCommercialSalesElectricOperatingRevenue | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| (e) Concept: MiscellaneousServiceRevenues | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| (f) Concept: OtherElectricRevenue | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Other Electric Revenues include:
| ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
REGIONAL TRANSMISSION SERVICE REVENUES (Account 457.1) |
|||||
|
|||||
| Line No. |
Description of Service (a) |
Balance at End of Quarter 1 (b) |
Balance at End of Quarter 2 (c) |
Balance at End of Quarter 3 (d) |
Balance at End of Year (e) |
| 1 | |||||
| 2 | |||||
| 46 |
TOTAL |
|
|
|
|
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
SALES OF ELECTRICITY BY RATE SCHEDULES |
||||||
|
||||||
| Line No. |
Number and Title of Rate Schedule (a) |
MWh Sold (b) |
Revenue (c) |
Average Number of Customers (d) |
KWh of Sales Per Customer (e) |
Revenue Per KWh Sold (f) |
| 1 |
|
|
|
|
|
|
| 2 |
|
|
|
|
|
|
| 3 |
|
|
|
|
|
|
| 4 |
|
|
|
|
|
|
| 5 |
|
|
|
|
|
|
| 6 |
|
|
|
|
|
|
| 7 |
|
|
|
|
|
|
| 8 |
|
|
||||
| 9 |
|
|||||
| 41 | TOTAL Billed Residential Sales |
|
(a) |
|
|
|
| 42 | TOTAL Unbilled Rev. (See Instr. 6) | |||||
| 43 | TOTAL |
|
|
|
|
|
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: ResidentialSalesBilled | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
SALES OF ELECTRICITY BY RATE SCHEDULES |
||||||
|
||||||
| Line No. |
Number and Title of Rate Schedule (a) |
MWh Sold (b) |
Revenue (c) |
Average Number of Customers (d) |
KWh of Sales Per Customer (e) |
Revenue Per KWh Sold (f) |
| 1 |
|
|
|
|
|
|
| 2 |
|
|
|
|
|
|
| 3 |
|
|
|
|
|
|
| 4 |
|
|
|
|
|
|
| 5 |
|
|
|
|
||
| 6 |
|
|
|
|
|
|
| 7 |
|
|
|
|
|
|
| 8 |
|
|
|
|
|
|
| 9 |
|
|
|
|||
| 10 |
|
|||||
| 11 |
|
|
|
|
|
|
| 12 |
|
|||||
| 13 |
|
|||||
| 14 |
|
|||||
| 15 |
|
|
|
|||
| 16 |
|
|
|
|
|
|
| 17 |
|
|||||
| 18 |
|
|
|
|
|
|
| 19 |
|
|
|
|
|
|
| 20 |
|
|
|
|
|
|
| 21 |
|
|
|
|
|
|
| 22 |
|
|||||
| 41 | TOTAL Billed Small or Commercial |
|
(a) |
|
|
|
| 42 | TOTAL Unbilled Rev. Small or Commercial (See Instr. 6) | |||||
| 43 | TOTAL Small or Commercial |
|
(b) |
|
|
|
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: SmallOrCommercialSalesElectricOperatingRevenueBilled | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| (b) Concept: SmallOrCommercialSalesElectricOperatingRevenue | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
SALES OF ELECTRICITY BY RATE SCHEDULES |
||||||
|
||||||
| Line No. |
Number and Title of Rate Schedule (a) |
MWh Sold (b) |
Revenue (c) |
Average Number of Customers (d) |
KWh of Sales Per Customer (e) |
Revenue Per KWh Sold (f) |
| 1 |
|
|
|
|
|
|
| 2 |
|
|
|
|
|
|
| 3 |
|
|
|
|
|
|
| 4 |
|
|
|
|
||
| 5 |
|
|
|
|
||
| 6 |
|
|
|
|
|
|
| 7 |
|
|
|
|
|
|
| 8 |
|
|
|
|
|
|
| 9 |
|
|
|
|
|
|
| 10 |
|
|
|
|
|
|
| 11 |
|
|
|
|
|
|
| 12 |
|
|
|
|
|
|
| 13 |
|
|
|
|
|
|
| 14 |
|
|
|
|
|
|
| 15 |
|
|
||||
| 16 |
|
|
||||
| 41 | TOTAL Billed Large (or Ind.) Sales |
|
(a) |
|
|
|
| 42 | TOTAL Unbilled Rev. Large (or Ind.) (See Instr. 6) | |||||
| 43 | TOTAL Large (or Ind.) |
|
|
|
|
|
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: LargeOrIndustrialSalesElectricOperatingRevenueBilled | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
SALES OF ELECTRICITY BY RATE SCHEDULES |
||||||
|
||||||
| Line No. |
Number and Title of Rate Schedule (a) |
MWh Sold (b) |
Revenue (c) |
Average Number of Customers (d) |
KWh of Sales Per Customer (e) |
Revenue Per KWh Sold (f) |
| 1 |
|
|
|
|
|
|
| 2 |
|
|
|
|
|
|
| 3 |
|
|
|
|
|
|
| 4 |
|
|
|
|
|
|
| 41 | TOTAL Billed Public Street and Highway Lighting |
|
(a) |
|
|
|
| 42 | TOTAL Unbilled Rev. (See Instr. 6) | |||||
| 43 | TOTAL |
|
|
|
|
|
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: PublicStreetAndHighwayLightingBilled | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
SALES OF ELECTRICITY BY RATE SCHEDULES |
||||||
|
||||||
| Line No. |
Number and Title of Rate Schedule (a) |
MWh Sold (b) |
Revenue (c) |
Average Number of Customers (d) |
KWh of Sales Per Customer (e) |
Revenue Per KWh Sold (f) |
| 1 |
|
|
|
|
|
|
| 2 |
|
|
|
|
|
|
| 3 |
|
|
|
|
|
|
| 4 |
|
|||||
| 5 |
|
|
||||
| 6 |
|
|
|
|
|
|
| 7 |
|
|
|
|
|
|
| 8 |
|
|
|
|
|
|
| 9 |
|
|
|
|
||
| 41 | TOTAL Billed Other Sales to Public Authorities |
|
(a) |
|
|
|
| 42 | TOTAL Unbilled Rev. (See Instr. 6) | |||||
| 43 | TOTAL |
|
|
|
|
|
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: OtherSalesToPublicAuthoritiesBilled | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
SALES OF ELECTRICITY BY RATE SCHEDULES |
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| Line No. |
Number and Title of Rate Schedule (a) |
MWh Sold (b) |
Revenue (c) |
Average Number of Customers (d) |
KWh of Sales Per Customer (e) |
Revenue Per KWh Sold (f) |
| 41 | TOTAL Billed - All Accounts |
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| 42 | TOTAL Unbilled Rev. (See Instr. 6) - All Accounts | |||||
| 43 | TOTAL - All Accounts |
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Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
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SALES FOR RESALE (Account 447) |
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| ACTUAL DEMAND (MW) | REVENUE | ||||||||||
| Line No. |
Name of Company or Public Authority (Footnote Affiliations) (a) |
Statistical Classification (b) |
FERC Rate Schedule or Tariff Number (c) |
Average Monthly Billing Demand (MW) (d) |
Average Monthly NCP Demand (e) |
Average Monthly CP Demand (f) |
Megawatt Hours Sold (g) |
Demand Charges ($) (h) |
Energy Charges ($) (i) |
Other Charges ($) (j) |
Total ($) (h+i+j) (k) |
| 1 |
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(a) |
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| 15 |
Subtotal - RQ |
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| 16 |
Subtotal-Non-RQ |
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| 17 | Total |
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Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: OtherChargesRevenueSalesForResale | ||||||||||||||||||||||||||||||
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Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
ELECTRIC OPERATION AND MAINTENANCE EXPENSES |
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|
If the amount for previous year is not derived from previously reported figures, explain in footnote. |
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| Line No. |
Account (a) |
Amount for Current Year (b) |
Amount for Previous Year (c) (c) |
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1 |
PowerProductionExpensesAbstract 1. POWER PRODUCTION EXPENSES |
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2 |
SteamPowerGenerationAbstract A. Steam Power Generation |
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3 |
SteamPowerGenerationOperationAbstract Operation |
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4 |
OperationSupervisionAndEngineeringSteamPowerGeneration (500) Operation Supervision and Engineering |
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5 |
FuelSteamPowerGeneration (501) Fuel |
(a) |
(b) |
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6 |
SteamExpensesSteamPowerGeneration (502) Steam Expenses |
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7 |
SteamFromOtherSources (503) Steam from Other Sources |
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8 |
SteamTransferredCredit (Less) (504) Steam Transferred-Cr. |
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9 |
ElectricExpensesSteamPowerGeneration (505) Electric Expenses |
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10 |
MiscellaneousSteamPowerExpenses (506) Miscellaneous Steam Power Expenses |
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11 |
RentsSteamPowerGeneration (507) Rents |
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12 |
Allowances (509) Allowances |
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13 |
SteamPowerGenerationOperationsExpense TOTAL Operation (Enter Total of Lines 4 thru 12) |
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14 |
SteamPowerGenerationMaintenanceAbstract Maintenance |
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15 |
MaintenanceSupervisionAndEngineeringSteamPowerGeneration (510) Maintenance Supervision and Engineering |
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16 |
MaintenanceOfStructuresSteamPowerGeneration (511) Maintenance of Structures |
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17 |
MaintenanceOfBoilerPlantSteamPowerGeneration (512) Maintenance of Boiler Plant |
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18 |
MaintenanceOfElectricPlantSteamPowerGeneration (513) Maintenance of Electric Plant |
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19 |
MaintenanceOfMiscellaneousSteamPlant (514) Maintenance of Miscellaneous Steam Plant |
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20 |
SteamPowerGenerationMaintenanceExpense TOTAL Maintenance (Enter Total of Lines 15 thru 19) |
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21 |
PowerProductionExpensesSteamPower TOTAL Power Production Expenses-Steam Power (Enter Total of Lines 13 & 20) |
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22 |
NuclearPowerGenerationAbstract B. Nuclear Power Generation |
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23 |
NuclearPowerGenerationOperationAbstract Operation |
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24 |
OperationSupervisionAndEngineeringNuclearPowerGeneration (517) Operation Supervision and Engineering |
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25 |
NuclearFuelExpense (518) Fuel |
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26 |
CoolantsAndWater (519) Coolants and Water |
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27 |
SteamExpensesNuclearPowerGeneration (520) Steam Expenses |
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28 |
SteamFromOtherSourcesNuclearPowerGeneration (521) Steam from Other Sources |
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29 |
SteamTransferredCreditNuclearPowerGeneration (Less) (522) Steam Transferred-Cr. |
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30 |
ElectricExpensesNuclearPowerGeneration (523) Electric Expenses |
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31 |
MiscellaneousNuclearPowerExpenses (524) Miscellaneous Nuclear Power Expenses |
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32 |
RentsNuclearPowerGeneration (525) Rents |
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33 |
NuclearPowerGenerationOperationsExpense TOTAL Operation (Enter Total of lines 24 thru 32) |
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34 |
NuclearPowerGenerationMaintenanceAbstract Maintenance |
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35 |
MaintenanceSupervisionAndEngineeringNuclearPowerGeneration (528) Maintenance Supervision and Engineering |
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36 |
MaintenanceOfStructuresNuclearPowerGeneration (529) Maintenance of Structures |
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37 |
MaintenanceOfReactorPlantEquipmentNuclearPowerGeneration (530) Maintenance of Reactor Plant Equipment |
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38 |
MaintenanceOfElectricPlantNuclearPowerGeneration (531) Maintenance of Electric Plant |
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39 |
MaintenanceOfMiscellaneousNuclearPlant (532) Maintenance of Miscellaneous Nuclear Plant |
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40 |
NuclearPowerGenerationMaintenanceExpense TOTAL Maintenance (Enter Total of lines 35 thru 39) |
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41 |
PowerProductionExpensesNuclearPower TOTAL Power Production Expenses-Nuclear. Power (Enter Total of lines 33 & 40) |
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42 |
HydraulicPowerGenerationAbstract C. Hydraulic Power Generation |
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43 |
HydraulicPowerGenerationOperationAbstract Operation |
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44 |
OperationSupervisionAndEngineeringHydraulicPowerGeneration (535) Operation Supervision and Engineering |
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45 |
WaterForPower (536) Water for Power |
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46 |
HydraulicExpenses (537) Hydraulic Expenses |
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47 |
ElectricExpensesHydraulicPowerGeneration (538) Electric Expenses |
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48 |
MiscellaneousHydraulicPowerGenerationExpenses (539) Miscellaneous Hydraulic Power Generation Expenses |
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49 |
RentsHydraulicPowerGeneration (540) Rents |
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50 |
HydraulicPowerGenerationOperationsExpense TOTAL Operation (Enter Total of Lines 44 thru 49) |
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51 |
HydraulicPowerGenerationContinuedAbstract C. Hydraulic Power Generation (Continued) |
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52 |
HydraulicPowerGenerationMaintenanceAbstract Maintenance |
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53 |
MaintenanceSupervisionAndEngineeringHydraulicPowerGeneration (541) Mainentance Supervision and Engineering |
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54 |
MaintenanceOfStructuresHydraulicPowerGeneration (542) Maintenance of Structures |
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55 |
MaintenanceOfReservoirsDamsAndWaterways (543) Maintenance of Reservoirs, Dams, and Waterways |
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56 |
MaintenanceOfElectricPlantHydraulicPowerGeneration (544) Maintenance of Electric Plant |
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57 |
MaintenanceOfMiscellaneousHydraulicPlant (545) Maintenance of Miscellaneous Hydraulic Plant |
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58 |
HydraulicPowerGenerationMaintenanceExpense TOTAL Maintenance (Enter Total of lines 53 thru 57) |
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59 |
PowerProductionExpensesHydraulicPower TOTAL Power Production Expenses-Hydraulic Power (Total of Lines 50 & 58) |
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60 |
OtherPowerGenerationAbstract D. Other Power Generation |
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61 |
OtherPowerGenerationOperationAbstract Operation |
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62 |
OperationSupervisionAndEngineeringOtherPowerGeneration (546) Operation Supervision and Engineering |
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63 |
Fuel (547) Fuel |
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64 |
GenerationExpenses (548) Generation Expenses |
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|
64.1 |
OperationOfEnergyStorageEquipment (548.1) Operation of Energy Storage Equipment |
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65 |
MiscellaneousOtherPowerGenerationExpenses (549) Miscellaneous Other Power Generation Expenses |
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66 |
RentsOtherPowerGeneration (550) Rents |
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67 |
OtherPowerGenerationOperationsExpense TOTAL Operation (Enter Total of Lines 62 thru 67) |
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68 |
OtherPowerGenerationMaintenanceAbstract Maintenance |
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69 |
MaintenanceSupervisionAndEngineeringOtherPowerGeneration (551) Maintenance Supervision and Engineering |
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70 |
MaintenanceOfStructures (552) Maintenance of Structures |
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71 |
MaintenanceOfGeneratingAndElectricPlant (553) Maintenance of Generating and Electric Plant |
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71.1 |
MaintenanceOfEnergyStorageEquipmentOtherPowerGeneration (553.1) Maintenance of Energy Storage Equipment |
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72 |
MaintenanceOfMiscellaneousOtherPowerGenerationPlant (554) Maintenance of Miscellaneous Other Power Generation Plant |
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73 |
OtherPowerGenerationMaintenanceExpense TOTAL Maintenance (Enter Total of Lines 69 thru 72) |
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74 |
PowerProductionExpensesOtherPower TOTAL Power Production Expenses-Other Power (Enter Total of Lines 67 & 73) |
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|
75 |
OtherPowerSuplyExpensesAbstract E. Other Power Supply Expenses |
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|
76 |
PurchasedPower (555) Purchased Power |
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|
76.1 |
PowerPurchasedForStorageOperations (555.1) Power Purchased for Storage Operations |
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77 |
SystemControlAndLoadDispatchingElectric (556) System Control and Load Dispatching |
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78 |
OtherExpensesOtherPowerSupplyExpenses (557) Other Expenses |
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79 |
OtherPowerSupplyExpense TOTAL Other Power Supply Exp (Enter Total of Lines 76 thru 78) |
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80 |
PowerProductionExpenses TOTAL Power Production Expenses (Total of Lines 21, 41, 59, 74 & 79) |
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81 |
TransmissionExpensesAbstract 2. TRANSMISSION EXPENSES |
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|
82 |
TransmissionExpensesOperationAbstract Operation |
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|
83 |
OperationSupervisionAndEngineeringElectricTransmissionExpenses (560) Operation Supervision and Engineering |
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|
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85 |
LoadDispatchReliability (561.1) Load Dispatch-Reliability |
||
|
86 |
LoadDispatchMonitorAndOperateTransmissionSystem (561.2) Load Dispatch-Monitor and Operate Transmission System |
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|
|
87 |
LoadDispatchTransmissionServiceAndScheduling (561.3) Load Dispatch-Transmission Service and Scheduling |
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|
88 |
SchedulingSystemControlAndDispatchServices (561.4) Scheduling, System Control and Dispatch Services |
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89 |
ReliabilityPlanningAndStandardsDevelopment (561.5) Reliability, Planning and Standards Development |
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|
90 |
TransmissionServiceStudies (561.6) Transmission Service Studies |
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|
91 |
GenerationInterconnectionStudies (561.7) Generation Interconnection Studies |
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|
92 |
ReliabilityPlanningAndStandardsDevelopmentServices (561.8) Reliability, Planning and Standards Development Services |
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93 |
StationExpensesTransmissionExpense (562) Station Expenses |
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|
93.1 |
OperationOfEnergyStorageEquipmentTransmissionExpense (562.1) Operation of Energy Storage Equipment |
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|
94 |
OverheadLineExpense (563) Overhead Lines Expenses |
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|
95 |
UndergroundLineExpensesTransmissionExpense (564) Underground Lines Expenses |
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96 |
TransmissionOfElectricityByOthers (565) Transmission of Electricity by Others |
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97 |
MiscellaneousTransmissionExpenses (566) Miscellaneous Transmission Expenses |
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98 |
RentsTransmissionElectricExpense (567) Rents |
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99 |
TransmissionOperationExpense TOTAL Operation (Enter Total of Lines 83 thru 98) |
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100 |
TransmissionMaintenanceAbstract Maintenance |
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101 |
MaintenanceSupervisionAndEngineeringElectricTransmissionExpenses (568) Maintenance Supervision and Engineering |
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102 |
MaintenanceOfStructuresTransmissionExpense (569) Maintenance of Structures |
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103 |
MaintenanceOfComputerHardwareTransmission (569.1) Maintenance of Computer Hardware |
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104 |
MaintenanceOfComputerSoftwareTransmission (569.2) Maintenance of Computer Software |
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105 |
MaintenanceOfCommunicationEquipmentElectricTransmission (569.3) Maintenance of Communication Equipment |
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106 |
MaintenanceOfMiscellaneousRegionalTransmissionPlant (569.4) Maintenance of Miscellaneous Regional Transmission Plant |
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|
107 |
MaintenanceOfStationEquipmentTransmission (570) Maintenance of Station Equipment |
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107.1 |
MaintenanceOfEnergyStorageEquipmentTransmission (570.1) Maintenance of Energy Storage Equipment |
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108 |
MaintenanceOfOverheadLinesTransmission (571) Maintenance of Overhead Lines |
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109 |
MaintenanceOfUndergroundLinesTransmission (572) Maintenance of Underground Lines |
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110 |
MaintenanceOfMiscellaneousTransmissionPlant (573) Maintenance of Miscellaneous Transmission Plant |
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111 |
TransmissionMaintenanceExpenseElectric TOTAL Maintenance (Total of Lines 101 thru 110) |
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112 |
TransmissionExpenses TOTAL Transmission Expenses (Total of Lines 99 and 111) |
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113 |
RegionalMarketExpensesAbstract 3. REGIONAL MARKET EXPENSES |
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|
114 |
RegionalMarketExpensesOperationAbstract Operation |
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115 |
OperationSupervision (575.1) Operation Supervision |
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116 |
DayAheadAndRealTimeMarketAdministration (575.2) Day-Ahead and Real-Time Market Facilitation |
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117 |
TransmissionRightsMarketAdministration (575.3) Transmission Rights Market Facilitation |
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118 |
CapacityMarketAdministration (575.4) Capacity Market Facilitation |
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119 |
AncillaryServicesMarketAdministration (575.5) Ancillary Services Market Facilitation |
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120 |
MarketMonitoringAndCompliance (575.6) Market Monitoring and Compliance |
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121 |
MarketFacilitationMonitoringAndComplianceServices (575.7) Market Facilitation, Monitoring and Compliance Services |
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122 |
RentsRegionalMarketExpenses (575.8) Rents |
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123 |
RegionalMarketOperationExpense Total Operation (Lines 115 thru 122) |
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124 |
RegionalMarketExpensesMaintenanceAbstract Maintenance |
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125 |
MaintenanceOfStructuresAndImprovementsRegionalMarketExpenses (576.1) Maintenance of Structures and Improvements |
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126 |
MaintenanceOfComputerHardware (576.2) Maintenance of Computer Hardware |
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127 |
MaintenanceOfComputerSoftware (576.3) Maintenance of Computer Software |
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128 |
MaintenanceOfCommunicationEquipmentRegionalMarketExpenses (576.4) Maintenance of Communication Equipment |
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129 |
MaintenanceOfMiscellaneousMarketOperationPlant (576.5) Maintenance of Miscellaneous Market Operation Plant |
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130 |
RegionalMarketMaintenanceExpense Total Maintenance (Lines 125 thru 129) |
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131 |
RegionalMarketExpenses TOTAL Regional Transmission and Market Operation Expenses (Enter Total of Lines 123 and 130) |
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132 |
DistributionExpensesAbstract 4. DISTRIBUTION EXPENSES |
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133 |
DistributionExpensesOperationAbstract Operation |
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134 |
OperationSupervisionAndEngineeringDistributionExpense (580) Operation Supervision and Engineering |
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135 |
LoadDispatching (581) Load Dispatching |
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136 |
StationExpensesDistribution (582) Station Expenses |
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137 |
OverheadLineExpenses (583) Overhead Line Expenses |
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138 |
UndergroundLineExpenses (584) Underground Line Expenses |
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138.1 |
OperationOfEnergyStorageEquipmentDistribution (584.1) Operation of Energy Storage Equipment |
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139 |
StreetLightingAndSignalSystemExpenses (585) Street Lighting and Signal System Expenses |
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140 |
MeterExpenses (586) Meter Expenses |
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141 |
CustomerInstallationsExpenses (587) Customer Installations Expenses |
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142 |
MiscellaneousDistributionExpenses (588) Miscellaneous Expenses |
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143 |
RentsDistributionExpense (589) Rents |
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144 |
DistributionOperationExpensesElectric TOTAL Operation (Enter Total of Lines 134 thru 143) |
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145 |
DistributionExpensesMaintenanceAbstract Maintenance |
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146 |
MaintenanceSupervisionAndEngineering (590) Maintenance Supervision and Engineering |
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147 |
MaintenanceOfStructuresDistributionExpense (591) Maintenance of Structures |
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148 |
MaintenanceOfStationEquipment (592) Maintenance of Station Equipment |
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148.1 |
MaintenanceOfEnergyStorageEquipment (592.2) Maintenance of Energy Storage Equipment |
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149 |
MaintenanceOfOverheadLines (593) Maintenance of Overhead Lines |
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150 |
MaintenanceOfUndergroundLines (594) Maintenance of Underground Lines |
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151 |
MaintenanceOfLineTransformers (595) Maintenance of Line Transformers |
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152 |
MaintenanceOfStreetLightingAndSignalSystems (596) Maintenance of Street Lighting and Signal Systems |
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153 |
MaintenanceOfMeters (597) Maintenance of Meters |
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154 |
MaintenanceOfMiscellaneousDistributionPlant (598) Maintenance of Miscellaneous Distribution Plant |
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155 |
DistributionMaintenanceExpenseElectric TOTAL Maintenance (Total of Lines 146 thru 154) |
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156 |
DistributionExpenses TOTAL Distribution Expenses (Total of Lines 144 and 155) |
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157 |
CustomerAccountsExpensesAbstract 5. CUSTOMER ACCOUNTS EXPENSES |
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|
158 |
CustomerAccountsExpensesOperationsAbstract Operation |
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|
159 |
SupervisionCustomerAccountExpenses (901) Supervision |
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160 |
MeterReadingExpenses (902) Meter Reading Expenses |
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161 |
CustomerRecordsAndCollectionExpenses (903) Customer Records and Collection Expenses |
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162 |
UncollectibleAccounts (904) Uncollectible Accounts |
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163 |
MiscellaneousCustomerAccountsExpenses (905) Miscellaneous Customer Accounts Expenses |
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164 |
CustomerAccountExpenses TOTAL Customer Accounts Expenses (Enter Total of Lines 159 thru 163) |
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165 |
CustomerServiceAndInformationalExpensesAbstract 6. CUSTOMER SERVICE AND INFORMATIONAL EXPENSES |
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166 |
CustomerServiceAndInformationalExpensesOperationAbstract Operation |
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167 |
SupervisionCustomerServiceAndInformationExpenses (907) Supervision |
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168 |
CustomerAssistanceExpenses (908) Customer Assistance Expenses |
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169 |
InformationalAndInstructionalAdvertisingExpenses (909) Informational and Instructional Expenses |
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170 |
MiscellaneousCustomerServiceAndInformationalExpenses (910) Miscellaneous Customer Service and Informational Expenses |
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171 |
CustomerServiceAndInformationExpenses TOTAL Customer Service and Information Expenses (Total Lines 167 thru 170) |
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172 |
SalesExpenseAbstract 7. SALES EXPENSES |
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173 |
SalesExpenseOperationAbstract Operation |
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174 |
SupervisionSalesExpense (911) Supervision |
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175 |
DemonstratingAndSellingExpenses (912) Demonstrating and Selling Expenses |
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176 |
AdvertisingExpenses (913) Advertising Expenses |
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177 |
MiscellaneousSalesExpenses (916) Miscellaneous Sales Expenses |
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178 |
SalesExpenses TOTAL Sales Expenses (Enter Total of Lines 174 thru 177) |
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179 |
AdministrativeAndGeneralExpensesAbstract 8. ADMINISTRATIVE AND GENERAL EXPENSES |
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180 |
AdministrativeAndGeneralExpensesOperationAbstract Operation |
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181 |
AdministrativeAndGeneralSalaries (920) Administrative and General Salaries |
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182 |
OfficeSuppliesAndExpenses (921) Office Supplies and Expenses |
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183 |
AdministrativeExpensesTransferredCredit (Less) (922) Administrative Expenses Transferred-Credit |
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184 |
OutsideServicesEmployed (923) Outside Services Employed |
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185 |
PropertyInsurance (924) Property Insurance |
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186 |
InjuriesAndDamages (925) Injuries and Damages |
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187 |
EmployeePensionsAndBenefits (926) Employee Pensions and Benefits |
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188 |
FranchiseRequirements (927) Franchise Requirements |
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|
189 |
RegulatoryCommissionExpenses (928) Regulatory Commission Expenses |
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190 |
DuplicateChargesCredit (929) (Less) Duplicate Charges-Cr. |
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191 |
GeneralAdvertisingExpenses (930.1) General Advertising Expenses |
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192 |
MiscellaneousGeneralExpenses (930.2) Miscellaneous General Expenses |
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193 |
RentsAdministrativeAndGeneralExpense (931) Rents |
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194 |
AdministrativeAndGeneralOperationExpense TOTAL Operation (Enter Total of Lines 181 thru 193) |
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195 |
AdministrativeAndGeneralExpensesMaintenanceAbstract Maintenance |
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196 |
MaintenanceOfGeneralPlant (935) Maintenance of General Plant |
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197 |
AdministrativeAndGeneralExpenses TOTAL Administrative & General Expenses (Total of Lines 194 and 196) |
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198 |
OperationsAndMaintenanceExpensesElectric TOTAL Electric Operation and Maintenance Expenses (Total of Lines 80, 112, 131, 156, 164, 171, 178, and 197) |
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Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: FuelSteamPowerGeneration |
| (b) Concept: FuelSteamPowerGeneration |
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
PURCHASED POWER (Account 555) |
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| Actual Demand (MW) | POWER EXCHANGES | COST/SETTLEMENT OF POWER | ||||||||||||
| Line No. |
NameOfCompanyOrPublicAuthorityProvidingPurchasedPower Name of Company or Public Authority (Footnote Affiliations) (a) |
StatisticalClassificationCode Statistical Classification (b) |
RateScheduleTariffNumber Ferc Rate Schedule or Tariff Number (c) |
AverageMonthlyBillingDemand Average Monthly Billing Demand (MW) (d) |
AverageMonthlyNonCoincidentPeakDemand Average Monthly NCP Demand (e) |
AverageMonthlyCoincidentPeakDemand Average Monthly CP Demand (f) |
MegawattHoursPurchasedOtherThanStorage MegaWatt Hours Purchased (Excluding for Energy Storage) (g) |
MegawattHoursPurchasedForEnergyStorage MegaWatt Hours Purchased for Energy Storage (h) |
EnergyReceivedThroughPowerExchanges MegaWatt Hours Received (i) |
EnergyDeliveredThroughPowerExchanges MegaWatt Hours Delivered (j) |
DemandChargesOfPurchasedPower Demand Charges ($) (k) |
EnergyChargesOfPurchasedPower Energy Charges ($) (l) |
OtherChargesOfPurchasedPower Other Charges ($) (m) |
SettlementOfPower Total (k+l+m) of Settlement ($) (n) |
| 1 | (a) |
(c) |
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| 2 | (b) |
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| 3 | ||||||||||||||
| 4 | ||||||||||||||
| 5 | (d) |
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| 6 | ||||||||||||||
| 7 | (e) |
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| 8 | (f) |
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| 9 | (g) |
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| 15 | TOTAL |
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Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: NameOfCompanyOrPublicAuthorityProvidingPurchasedPower | ||||||||||||||||||||||||||||||||||||||||||||||||||||||
| (b) Concept: NameOfCompanyOrPublicAuthorityProvidingPurchasedPower | ||||||||||||||||||||||||||||||||||||||||||||||||||||||
| (c) Concept: OtherChargesOfPurchasedPower | ||||||||||||||||||||||||||||||||||||||||||||||||||||||
| (d) Concept: OtherChargesOfPurchasedPower | ||||||||||||||||||||||||||||||||||||||||||||||||||||||
| ||||||||||||||||||||||||||||||||||||||||||||||||||||||
| (e) Concept: OtherChargesOfPurchasedPower | ||||||||||||||||||||||||||||||||||||||||||||||||||||||
| (f) Concept: OtherChargesOfPurchasedPower | ||||||||||||||||||||||||||||||||||||||||||||||||||||||
| (g) Concept: OtherChargesOfPurchasedPower | ||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling") |
||||||||||||||
|
||||||||||||||
| TRANSFER OF ENERGY | REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS | |||||||||||||
| Line No. |
PaymentByCompanyOrPublicAuthority Payment By (Company of Public Authority) (Footnote Affiliation) (a) |
TransmissionEnergyReceivedFromCompanyOrPublicAuthorityName Energy Received From (Company of Public Authority) (Footnote Affiliation) (b) |
TransmissionEnergyDeliveredToCompanyOrPublicAuthorityName Energy Delivered To (Company of Public Authority) (Footnote Affiliation) (c) |
StatisticalClassificationCode Statistical Classification (d) |
RateScheduleTariffNumber Ferc Rate Schedule of Tariff Number (e) |
TransmissionPointOfReceipt Point of Receipt (Substation or Other Designation) (f) |
TransmissionPointOfDelivery Point of Delivery (Substation or Other Designation) (g) |
BillingDemand Billing Demand (MW) (h) |
TransmissionOfElectricityForOthersEnergyReceived Megawatt Hours Received (i) |
TransmissionOfElectricityForOthersEnergyDelivered Megawatt Hours Delivered (j) |
Demand Charges ($) (k) |
Energy Charges ($) (l) |
Other Charges ($) (m) |
RevenuesFromTransmissionOfElectricityForOthers Total Revenues ($) (k+l+m) (n) |
| 1 |
|
|
|
|
|
|
|
|||||||
| 35 | TOTAL |
|
|
|
|
|
||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
TRANSMISSION OF ELECTRICITY BY ISO/RTOs |
|||||
|
|||||
| Line No. |
Payment Received by (Transmission Owner Name) (a) |
Statistical Classification (b) |
FERC Rate Schedule or Tariff Number (c) |
Total Revenue by Rate Schedule or Tariff (d) |
Total Revenue (e) |
| 1 | |||||
| 2 | |||||
| 3 | |||||
| 4 | |||||
| 5 | |||||
| 6 | |||||
| 7 | |||||
| 8 | |||||
| 9 | |||||
| 10 | |||||
| 11 | |||||
| 12 | |||||
| 13 | |||||
| 14 | |||||
| 15 | |||||
| 16 | |||||
| 17 | |||||
| 18 | |||||
| 19 | |||||
| 20 | |||||
| 21 | |||||
| 22 | |||||
| 23 | |||||
| 24 | |||||
| 25 | |||||
| 26 | |||||
| 27 | |||||
| 28 | |||||
| 29 | |||||
| 30 | |||||
| 31 | |||||
| 32 | |||||
| 33 | |||||
| 34 | |||||
| 35 | |||||
| 36 | |||||
| 37 | |||||
| 38 | |||||
| 39 | |||||
| 40 | |||||
| 41 | |||||
| 42 | |||||
| 43 | |||||
| 44 | |||||
| 45 | |||||
| 46 | |||||
| 47 | |||||
| 48 | |||||
| 49 | |||||
| 40 |
TOTAL |
||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
TRANSMISSION OF ELECTRICITY BY OTHERS (Account 565) |
||||||||
|
||||||||
| TRANSFER OF ENERGY | EXPENSES FOR TRANSMISSION OF ELECTRICITY BY OTHERS | |||||||
| Line No. |
NameOfCompanyOrPublicAuthorityTransmissionOfElectricityByOthers Name of Company or Public Authority (Footnote Affiliations) (a) |
StatisticalClassificationCode Statistical Classification (b) |
TransmissionOfElectricityByOthersEnergyReceived MegaWatt Hours Received (c) |
TransmissionOfElectricityByOthersEnergyDelivered MegaWatt Hours Delivered (d) |
DemandChargesTransmissionOfElectricityByOthers Demand Charges ($) (e) |
EnergyChargesTransmissionOfElectricityByOthers Energy Charges ($) (f) |
OtherChargesTransmissionOfElectricityByOthers Other Charges ($) (g) |
ChargesForTransmissionOfElectricityByOthers Total Cost of Transmission ($) (h) |
| 1 |
|
(a) |
(b) |
|
||||
|
TOTAL |
|
|
|
|
|
|
||
| FOOTNOTE DATA |
| (a) Concept: DemandChargesTransmissionOfElectricityByOthers |
| (b) Concept: OtherChargesTransmissionOfElectricityByOthers |
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
MISCELLANEOUS GENERAL EXPENSES (Account 930.2) (ELECTRIC) |
||
| Line No. |
Description (a) |
Amount (b) |
| 1 |
IndustryAssociationDues
Industry Association Dues
|
|
| 2 |
NuclearPowerResearchExpenses
Nuclear Power Research Expenses
|
|
| 3 |
OtherExperimentalAndGeneralResearchExpenses
Other Experimental and General Research Expenses
|
|
| 4 |
PublicationAndDistributionExpensesForSecuritiesToStockholders
Pub and Dist Info to Stkhldrs...expn servicing outstanding Securities
|
|
| 5 |
OtherMiscellaneousGeneralExpenses
Oth Expn greater than or equal to 5,000 show purpose, recipient, amount. Group if less than $5,000
|
|
| 6 |
|
|
| 7 |
|
|
| 8 |
|
|
| 9 |
|
|
| 10 |
|
|
| 11 |
|
|
| 12 |
|
|
| 13 |
|
|
| 46 |
MiscellaneousGeneralExpenses
TOTAL
|
|
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
Depreciation and Amortization of Electric Plant (Account 403, 404, 405) |
||||||
|
||||||
| A. Summary of Depreciation and Amortization Charges | ||||||
| Line No. |
FunctionalClassificationAxis Functional Classification (a) |
DepreciationExpenseExcludingAmortizationOfAcquisitionAdjustments Depreciation Expense (Account 403) (b) |
DepreciationExpenseForAssetRetirementCostsExcludingAmortizationgOfAcquisitionAdjustments Depreciation Expense for Asset Retirement Costs (Account 403.1) (c) |
AmortizationOfLimitedTermPlantOrProperty Amortization of Limited Term Electric Plant (Account 404) (d) |
AmortizationOfOtherElectricPlant Amortization of Other Electric Plant (Acc 405) (e) |
DepreciationAndAmortization Total (f) |
| 1 |
Intangible Plant |
|
|
|||
| 2 |
Steam Production Plant |
|
|
|
||
| 3 |
Nuclear Production Plant |
|||||
| 4 |
Hydraulic Production Plant-Conventional |
|||||
| 5 |
Hydraulic Production Plant-Pumped Storage |
|||||
| 6 |
Other Production Plant |
|
|
|||
| 7 |
Transmission Plant |
|
|
|||
| 8 |
Distribution Plant |
|
|
|||
| 9 |
Regional Transmission and Market Operation |
|||||
| 10 |
General Plant |
(a) |
|
|||
| 11 |
Common Plant-Electric |
|||||
| 12 |
TOTAL |
|
|
|
|
|
| B. Basis for Amortization Charges | ||||||
| C. Factors Used in Estimating Depreciation Charges | ||||||||
| Line No. |
AccountNumberFactorsUsedInEstimatingDepreciationCharges Account No. (a) |
DepreciablePlantBase Depreciable Plant Base (in Thousands) (b) |
UtilityPlantEstimatedAverageServiceLife Estimated Avg. Service Life (c) |
UtilityPlantNetSalvageValuePercentage Net Salvage (Percent) (d) |
UtilityPlantAppliedDepreciationRate Applied Depr. Rates (Percent) (e) |
MortalityCurveType Mortality Curve Type (f) |
UtilityPlantWeightedAverageRemainingLife Average Remaining Life (g) |
|
| 12 | ||||||||
| 13 | ||||||||
| 14 | ||||||||
| 15 | ||||||||
| 16 | ||||||||
| 17 | ||||||||
| 18 | ||||||||
| 19 | ||||||||
| 20 | ||||||||
| 21 | ||||||||
| 22 | ||||||||
| 23 | ||||||||
| 24 | ||||||||
| 25 | ||||||||
| 26 | ||||||||
| 27 | ||||||||
| 28 | ||||||||
| 29 | ||||||||
| 30 | ||||||||
| 31 | ||||||||
| 32 | ||||||||
| 33 | ||||||||
| 34 | ||||||||
| 35 | ||||||||
| 36 | ||||||||
| 37 | ||||||||
| 38 | ||||||||
| 39 | ||||||||
| 40 | ||||||||
| 41 | ||||||||
| 42 | ||||||||
| 43 | ||||||||
| 44 | ||||||||
| 45 | ||||||||
| 46 | ||||||||
| 47 | ||||||||
| 48 | ||||||||
| 49 | ||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: DepreciationExpenseExcludingAmortizationOfAcquisitionAdjustments |
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
REGULATORY COMMISSION EXPENSES |
||||||||||||
|
||||||||||||
| EXPENSES INCURRED DURING YEAR | AMORTIZED DURING YEAR | |||||||||||
| CURRENTLY CHARGED TO | ||||||||||||
| Line No. |
RegulatoryCommissionDescription Description (Furnish name of regulatory commission or body the docket or case number and a description of the case) (a) |
RegulatoryExpensesAssessedByRegulatoryCommission Assessed by Regulatory Commission (b) |
RegulatoryExpensesOfUtility Expenses of Utility (c) |
RegulatoryCommissionExpensesAmount Total Expenses for Current Year (b) + (c) (d) |
OtherRegulatoryAssetsRegulatoryCommissionExpenses Deferred in Account 182.3 at Beginning of Year (e) |
NameOfDepartmentRegulatoryCommissionExpensesCharged Department (f) |
AccountNumberRegulatoryCommissionExpensesCharged Account No. (g) |
RegulatoryComissionExpensesIncurredAndCharged Amount (h) |
RegulatoryCommissionExpensesDeferredToOtherRegulatoryAssets Deferred to Account 182.3 (i) |
DeferredRegulatoryCommissionExpensesAmortizedInContraAccount Contra Account (j) |
DeferredRegulatoryCommissionExpensesAmortized Amount (k) |
OtherRegulatoryAssetsRegulatoryCommissionExpenses Deferred in Account 182.3 End of Year (l) |
| 1 |
|
|
|
|
|
|
||||||
| 2 |
|
|
|
|
|
|
||||||
| 3 |
|
|
|
|
|
|
||||||
| 4 |
|
|
|
|
|
|
||||||
| 5 |
|
|
|
|
|
|
|
|
|
|||
| 6 |
|
|
|
|
|
|
||||||
| 7 |
|
|
|
|
|
|
||||||
| 8 |
|
|
|
|
|
|
||||||
| 9 |
|
|
|
|
|
|
||||||
| 10 |
|
|
|
|
|
|
||||||
| 46 |
TOTAL |
|
|
|
|
|
|
|||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
RESEARCH, DEVELOPMENT, AND DEMONSTRATION ACTIVITIES |
|||||||
|
|||||||
| AMOUNTS CHARGED IN CURRENT YEAR | |||||||
| Line No. |
ResearchDevelopmentAndDemonstrationClassification Classification (a) |
ResearchDevelopmentAndDemonstrationDescription Description (b) |
ResearchDevelopmentAndDemonstrationCostsIncurredInternally Costs Incurred Internally Current Year (c) |
ResearchDevelopmentAndDemonstrationCostsIncurredExternally Costs Incurred Externally Current Year (d) |
AccountNumberForResearchDevelopmentAndDemonstrationCosts Amounts Charged In Current Year: Account (e) |
ResearchDevelopmentAndDemonstrationCosts Amounts Charged In Current Year: Amount (f) |
ResearchDevelopmentAndDemonstrationExpenditures Unamortized Accumulation (g) |
| 1 | |||||||
| 2 | |||||||
| 3 | |||||||
| 4 | |||||||
| 5 | |||||||
| 6 | |||||||
| 7 | |||||||
| 8 | |||||||
| 9 | |||||||
| 10 | |||||||
| 11 | |||||||
| 12 | |||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
DISTRIBUTION OF SALARIES AND WAGES |
|||||
|
Report below the distribution of total salaries and wages for the year. Segregate amounts originally charged to clearing accounts to Utility Departments, Construction, Plant Removals, and Other Accounts, and enter such amounts in the appropriate lines and columns provided. In determining this segregation of salaries and wages originally charged to clearing accounts, a method of approximation giving substantially correct results may be used. |
|||||
| Line No. |
Classification (a) |
Direct Payroll Distribution (b) |
Allocation of Payroll Charged for Clearing Accounts (c) |
Total (d) |
|
|
1 |
SalariesAndWagesElectricAbstract Electric |
||||
|
2 |
SalariesAndWagesElectricOperationAbstract Operation |
||||
|
3 |
SalariesAndWagesElectricOperationProduction Production |
|
|||
|
4 |
SalariesAndWagesElectricOperationTransmission Transmission |
|
|||
|
5 |
SalariesAndWagesElectricOperationRegionalMarket Regional Market |
||||
|
6 |
SalariesAndWagesElectricOperationDistribution Distribution |
|
|||
|
7 |
SalariesAndWagesElectricOperationCustomerAccounts Customer Accounts |
|
|||
|
8 |
SalariesAndWagesElectricOperationCustomerServiceAndInformational Customer Service and Informational |
|
|||
|
9 |
SalariesAndWagesElectricOperationSales Sales |
|
|||
|
10 |
SalariesAndWagesElectricOperationAdministrativeAndGeneral Administrative and General |
|
|||
|
11 |
SalariesAndWagesElectricOperation TOTAL Operation (Enter Total of lines 3 thru 10) |
|
|||
|
12 |
SalariesAndWagesElectricMaintenanceAbstract Maintenance |
||||
|
13 |
SalariesAndWagesElectricMaintenanceProduction Production |
|
|||
|
14 |
SalariesAndWagesElectricMaintenanceTransmission Transmission |
|
|||
|
15 |
SalariesAndWagesElectricMaintenanceRegionalMarket Regional Market |
||||
|
16 |
SalariesAndWagesElectricMaintenanceDistribution Distribution |
|
|||
|
17 |
SalariesAndWagesElectricMaintenanceAdministrativeAndGeneral Administrative and General |
|
|||
|
18 |
SalariesAndWagesElectricMaintenance TOTAL Maintenance (Total of lines 13 thru 17) |
|
|||
|
19 |
SalariesAndWagesElectricOperationAndMaintenanceAbstract Total Operation and Maintenance |
||||
|
20 |
SalariesAndWagesElectricProduction Production (Enter Total of lines 3 and 13) |
|
|||
|
21 |
SalariesAndWagesElectricTransmission Transmission (Enter Total of lines 4 and 14) |
|
|||
|
22 |
SalariesAndWagesElectricRegionalMarket Regional Market (Enter Total of Lines 5 and 15) |
||||
|
23 |
SalariesAndWagesElectricDistribution Distribution (Enter Total of lines 6 and 16) |
|
|||
|
24 |
SalariesAndWagesElectricCustomerAccounts Customer Accounts (Transcribe from line 7) |
|
|||
|
25 |
SalariesAndWagesElectricCustomerServiceAndInformational Customer Service and Informational (Transcribe from line 8) |
|
|||
|
26 |
SalariesAndWagesElectricSales Sales (Transcribe from line 9) |
|
|||
|
27 |
SalariesAndWagesElectricAdministrativeAndGeneral Administrative and General (Enter Total of lines 10 and 17) |
|
|||
|
28 |
SalariesAndWagesElectricOperationAndMaintenance TOTAL Oper. and Maint. (Total of lines 20 thru 27) |
|
|
||
|
29 |
SalariesAndWagesGasAbstract Gas |
||||
|
30 |
SalariesAndWagesGasOperationAbstract Operation |
||||
|
31 |
SalariesAndWagesGasOperationProductionManufacturedGas Production - Manufactured Gas |
||||
|
32 |
SalariesAndWagesGasOperationProductionNaturalGas Production-Nat. Gas (Including Expl. And Dev.) |
||||
|
33 |
SalariesAndWagesGasOperationOtherGasSupply Other Gas Supply |
||||
|
34 |
SalariesAndWagesGasOperationStorageLiquifiedNaturalGasTerminalingAndProcessing Storage, LNG Terminaling and Processing |
||||
|
35 |
SalariesAndWagesGasOperationTransmission Transmission |
||||
|
36 |
SalariesAndWagesGasOperationDistribution Distribution |
||||
|
37 |
SalariesAndWagesGasCustomerAccounts Customer Accounts |
||||
|
38 |
SalariesAndWagesGasCustomerServiceAndInformational Customer Service and Informational |
||||
|
39 |
SalariesAndWagesGasSales Sales |
||||
|
40 |
SalariesAndWagesGasOperationAdministrativeAndGeneral Administrative and General |
||||
|
41 |
SalariesAndWagesGasOperation TOTAL Operation (Enter Total of lines 31 thru 40) |
||||
|
42 |
SalariesAndWagesGasMaintenanceAbstract Maintenance |
||||
|
43 |
SalariesAndWagesGasMaintenanceProductionManufacturedGas Production - Manufactured Gas |
||||
|
44 |
SalariesAndWagesGasMaintenanceProductionNaturalGas Production-Natural Gas (Including Exploration and Development) |
||||
|
45 |
SalariesAndWagesGasMaintenanceOtherGasSupply Other Gas Supply |
||||
|
46 |
SalariesAndWagesGasMaintenanceStorageLngTerminalingAndProcessing Storage, LNG Terminaling and Processing |
||||
|
47 |
SalariesAndWagesGasMaintenanceTransmission Transmission |
||||
|
48 |
SalariesAndWagesGasMaintenanceDistribution Distribution |
||||
|
49 |
SalariesAndWagesGasMaintenanceAdministrativeAndGeneral Administrative and General |
||||
|
50 |
SalariesAndWagesGasMaintenance TOTAL Maint. (Enter Total of lines 43 thru 49) |
||||
|
51 |
SalariesAndWagesGasOperationAndMaintenanceAbstract Total Operation and Maintenance |
||||
|
52 |
SalariesAndWagesGasProductionManufacturedGas Production-Manufactured Gas (Enter Total of lines 31 and 43) |
||||
|
53 |
SalariesAndWagesGasProductionNaturalGas Production-Natural Gas (Including Expl. and Dev.) (Total lines 32, |
||||
|
54 |
SalariesAndWagesGasOtherGasSupply Other Gas Supply (Enter Total of lines 33 and 45) |
||||
|
55 |
SalariesAndWagesGasStorageLngTerminalingAndProcessing Storage, LNG Terminaling and Processing (Total of lines 31 thru |
||||
|
56 |
SalariesAndWagesGasTransmission Transmission (Lines 35 and 47) |
||||
|
57 |
SalariesAndWagesGasDistribution Distribution (Lines 36 and 48) |
||||
|
58 |
SalariesAndWagesGasCustomerAccounts Customer Accounts (Line 37) |
||||
|
59 |
SalariesAndWagesGasCustomerServiceAndInformational Customer Service and Informational (Line 38) |
||||
|
60 |
SalariesAndWagesGasSales Sales (Line 39) |
||||
|
61 |
SalariesAndWagesGasAdministrativeAndGeneral Administrative and General (Lines 40 and 49) |
||||
|
62 |
SalariesAndWagesGasOperationAndMaintenance TOTAL Operation and Maint. (Total of lines 52 thru 61) |
||||
|
63 |
SalariesAndWagesOtherUtilityDepartmentsAbstract Other Utility Departments |
||||
|
64 |
SalariesAndWagesOtherUtilityDepartmentsOperationAndMaintenance Operation and Maintenance |
||||
|
65 |
SalariesAndWagesOperationsAndMaintenance TOTAL All Utility Dept. (Total of lines 28, 62, and 64) |
|
|
||
|
66 |
SalariesAndWagesUtilityPlantAbstract Utility Plant |
||||
|
67 |
SalariesAndWagesUtilityPlantConstructionAbstract Construction (By Utility Departments) |
||||
|
68 |
SalariesAndWagesUtilityPlantConstructionElectricPlant Electric Plant |
|
|
||
|
69 |
SalariesAndWagesUtilityPlantConstructionGasPlant Gas Plant |
||||
|
70 |
SalariesAndWagesUtilityPlantConstructionOther Other (provide details in footnote): |
||||
|
71 |
SalariesAndWagesUtilityPlantConstruction TOTAL Construction (Total of lines 68 thru 70) |
|
|
||
|
72 |
SalariesAndWagesPlantRemovalAbstract Plant Removal (By Utility Departments) |
||||
|
73 |
SalariesAndWagesPlantRemovalElectricPlant Electric Plant |
|
|
||
|
74 |
SalariesAndWagesPlantRemovalGasPlant Gas Plant |
||||
|
75 |
SalariesAndWagesPlantRemovalOther Other (provide details in footnote): |
||||
|
76 |
SalariesAndWagesPlantRemoval TOTAL Plant Removal (Total of lines 73 thru 75) |
|
|
||
|
77 |
SalariesAndWagesOtherAccountsAbstract Other Accounts (Specify, provide details in footnote): |
||||
|
78 |
SalariesAndWagesOtherAccountsDescription |
||||
|
79 |
SalariesAndWagesOtherAccountsDescription |
|
|
||
|
80 |
SalariesAndWagesOtherAccountsDescription |
|
|
||
|
81 |
SalariesAndWagesOtherAccountsDescription |
|
|
||
|
82 |
SalariesAndWagesOtherAccountsDescription |
|
|
||
|
83 |
SalariesAndWagesOtherAccountsDescription |
|
|
||
|
84 |
SalariesAndWagesOtherAccountsDescription |
|
|
||
|
85 |
SalariesAndWagesOtherAccountsDescription |
|
|
||
|
86 |
SalariesAndWagesOtherAccountsDescription |
|
|
||
|
87 |
SalariesAndWagesOtherAccountsDescription |
|
|
||
|
88 |
SalariesAndWagesOtherAccountsDescription |
|
|
||
|
89 |
SalariesAndWagesOtherAccountsDescription |
||||
|
90 |
SalariesAndWagesOtherAccountsDescription |
||||
|
91 |
SalariesAndWagesOtherAccountsDescription |
||||
|
92 |
SalariesAndWagesOtherAccountsDescription |
||||
|
93 |
SalariesAndWagesOtherAccountsDescription |
||||
|
94 |
SalariesAndWagesOtherAccountsDescription |
||||
|
95 |
SalariesAndWagesOtherAccounts TOTAL Other Accounts |
|
|
||
|
96 |
SalariesAndWagesGeneralExpense TOTAL SALARIES AND WAGES |
|
(a) |
||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: SalariesAndWagesGeneralExpense | ||||||||||||||||||||||||||||||||||||||||||||||||||||||
The following payroll charges from Entergy Services are not included in this schedule and are included in the Electric O&M schedule (pages 320-323) only:
| ||||||||||||||||||||||||||||||||||||||||||||||||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
COMMON UTILITY PLANT AND EXPENSES |
||||
|
||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
AMOUNTS INCLUDED IN ISO/RTO SETTLEMENT STATEMENTS |
|||||
|
|||||
| Line No. |
Description of Item(s) (a) |
Balance at End of Quarter 1 (b) |
Balance at End of Quarter 2 (c) |
Balance at End of Quarter 3 (d) |
Balance at End of Year (e) |
| 1 | Energy | ||||
| 2 | Net Purchases (Account 555) |
|
|
|
|
| 2.1 | Net Purchases (Account 555.1) | ||||
| 3 | Net Sales (Account 447) |
|
|
|
|
| 4 | Transmission Rights | ||||
| 5 | Ancillary Services | ||||
| 6 | Other Items (list separately) | ||||
| 7 | |||||
| 8 | |||||
| 9 | |||||
| 10 | |||||
| 11 | |||||
| 12 | |||||
| 13 | |||||
| 14 | |||||
| 15 | |||||
| 16 | |||||
| 17 | |||||
| 18 | |||||
| 19 | |||||
| 20 | |||||
| 21 | |||||
| 22 | |||||
| 23 | |||||
| 24 | |||||
| 25 | |||||
| 26 | |||||
| 27 | |||||
| 28 | |||||
| 29 | |||||
| 30 | |||||
| 31 | |||||
| 32 | |||||
| 33 | |||||
| 34 | |||||
| 35 | |||||
| 36 | |||||
| 37 | |||||
| 38 | |||||
| 39 | |||||
| 40 | |||||
| 41 | |||||
| 42 | |||||
| 43 | |||||
| 44 | |||||
| 45 | |||||
| 46 | TOTAL |
|
|
|
|
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
PURCHASES AND SALES OF ANCILLARY SERVICES |
|||||||
|
Report the amounts for each type of ancillary service shown in column (a) for the year as specified in Order No. 888 and defined in the respondents Open Access Transmission Tariff. In columns for usage, report usage-related billing determinant and the unit of measure.
|
|||||||
| Amount Purchased for the Year | Amount Sold for the Year | ||||||
| Usage - Related Billing Determinant | Usage - Related Billing Determinant | ||||||
| Line No. |
Type of Ancillary Service (a) |
Number of Units (b) |
Unit of Measure (c) |
Dollar (d) |
Number of Units (e) |
Unit of Measure (f) |
Dollars (g) |
| 1 |
Scheduling, System Control and Dispatch |
|
|||||
| 2 |
Reactive Supply and Voltage |
|
|
||||
| 3 |
Regulation and Frequency Response |
||||||
| 4 |
Energy Imbalance |
||||||
| 5 |
Operating Reserve - Spinning |
||||||
| 6 |
Operating Reserve - Supplement |
||||||
| 7 |
Other |
||||||
| 8 |
Total (Lines 1 thru 7) |
|
(a) |
||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: AncillaryServicesSoldAmount |
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
MONTHLY TRANSMISSION SYSTEM PEAK LOAD |
||||||||||
|
||||||||||
| Line No. |
Month (a) |
Monthly Peak MW - Total (b) |
Day of Monthly Peak (c) |
Hour of Monthly Peak (d) |
Firm Network Service for Self (e) |
Firm Network Service for Others (f) |
Long-Term Firm Point-to-point Reservations (g) |
Other Long-Term Firm Service (h) |
Short-Term Firm Point-to-point Reservation (i) |
Other Service (j) |
NAME OF SYSTEM: Entergy Mississippi, LLC |
||||||||||
1 |
January |
|
||||||||
2 |
February |
|
||||||||
3 |
March |
|
||||||||
4 |
Total for Quarter 1 |
|||||||||
5 |
April |
|
||||||||
6 |
May |
|
||||||||
7 |
June |
|
||||||||
8 |
Total for Quarter 2 |
|||||||||
9 |
July |
|
||||||||
10 |
August |
|
||||||||
11 |
September |
|
||||||||
12 |
Total for Quarter 3 |
|||||||||
13 |
October |
|
||||||||
14 |
November |
|
||||||||
15 |
December |
|
||||||||
16 |
Total for Quarter 4 |
|||||||||
17 |
Total |
|||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
Monthly ISO/RTO Transmission System Peak Load |
||||||||||
|
||||||||||
| Line No. |
Month (a) |
Monthly Peak MW - Total (b) |
Day of Monthly Peak (c) |
Hour of Monthly Peak (d) |
Import into ISO/RTO (e) |
Exports from ISO/RTO (f) |
Through and Out Service (g) |
Network Service Usage (h) |
Point-to-Point Service Usage (i) |
Total Usage (j) |
NAME OF SYSTEM: 0 |
||||||||||
1 |
January |
|||||||||
2 |
February |
|||||||||
3 |
March |
|||||||||
4 |
Total for Quarter 1 |
|||||||||
5 |
April |
|||||||||
6 |
May |
|||||||||
7 |
June |
|||||||||
8 |
Total for Quarter 2 |
|||||||||
9 |
July |
|||||||||
10 |
August |
|||||||||
11 |
September |
|||||||||
12 |
Total for Quarter 3 |
|||||||||
13 |
October |
|||||||||
14 |
November |
|||||||||
15 |
December |
|||||||||
16 |
Total for Quarter 4 |
|||||||||
17 |
Total Year to Date/Year |
|||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
ELECTRIC ENERGY ACCOUNT |
|||||
|
Report below the information called for concerning the disposition of electric energy generated, purchased, exchanged and wheeled during the year. |
|||||
| Line No. |
Item
(a)
|
MegaWatt Hours
(b)
|
Line No. |
Item
(a)
|
MegaWatt Hours
(b)
|
| 1 |
SOURCES OF ENERGY |
21 |
DISPOSITION OF ENERGY |
||
| 2 |
Generation (Excluding Station Use): |
22 |
Sales to Ultimate Consumers (Including Interdepartmental Sales) |
|
|
| 3 |
Steam |
|
23 |
Requirements Sales for Resale (See instruction 4, page 311.) |
|
| 4 |
Nuclear |
24 |
Non-Requirements Sales for Resale (See instruction 4, page 311.) |
|
|
| 5 |
Hydro-Conventional |
25 |
Energy Furnished Without Charge |
||
| 6 |
Hydro-Pumped Storage |
26 |
Energy Used by the Company (Electric Dept Only, Excluding Station Use) |
|
|
| 7 |
Other |
|
27 |
Total Energy Losses |
|
| 8 |
Less Energy for Pumping |
27.1 |
Total Energy Stored |
||
| 9 |
Net Generation (Enter Total of lines 3 through 8) |
|
28 |
TOTAL (Enter Total of Lines 22 Through 27.1) MUST EQUAL LINE 20 UNDER SOURCES |
|
| 10 |
Purchases (other than for Energy Storage) |
|
|||
| 10.1 |
Purchases for Energy Storage |
|
|||
| 11 |
Power Exchanges: |
||||
| 12 |
Received |
|
|||
| 13 |
Delivered |
|
|||
| 14 |
Net Exchanges (Line 12 minus line 13) |
|
|||
| 15 |
Transmission For Other (Wheeling) |
||||
| 16 |
Received |
||||
| 17 |
Delivered |
||||
| 18 |
Net Transmission for Other (Line 16 minus line 17) |
|
|||
| 19 |
Transmission By Others Losses |
||||
| 20 |
TOTAL (Enter Total of Lines 9, 10, 10.1, 14, 18 and 19) |
|
|||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
MONTHLY PEAKS AND OUTPUT |
||||||
|
||||||
| Line No. |
MonthAxis Month (a) |
EnergyActivity Total Monthly Energy (b) |
NonRequiredSalesForResaleEnergy Monthly Non-Requirement Sales for Resale & Associated Losses (c) |
MonthlyPeakLoad Monthly Peak - Megawatts (d) |
DayOfMonthlyPeak Monthly Peak - Day of Month (e) |
HourOfMonthlyPeak Monthly Peak - Hour (f) |
NAME OF SYSTEM: Entergy Mississippi, LLC |
||||||
29 |
January |
|
||||
30 |
February |
|
||||
31 |
March |
|
||||
32 |
April |
|
||||
33 |
May |
|
||||
34 |
June |
|
||||
35 |
July |
|
||||
36 |
August |
|
||||
37 |
September |
|
||||
38 |
October |
|
||||
39 |
November |
|
||||
40 |
December |
|
||||
41 |
Total |
|
||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
Steam Electric Generating Plant Statistics |
|
1. Report data for plant in Service only. |
| Line No. |
Item
(a)
|
Plant Name:
|
Plant Name:
|
Plant Name:
|
Plant Name:
|
Plant Name:
|
Plant Name:
(a) |
| 1 |
PlantKind Kind of Plant (Internal Comb, Gas Turb, Nuclear) |
|
|
|
|
|
|
| 2 |
PlantConstructionType Type of Constr (Conventional, Outdoor, Boiler, etc) |
|
|
|
|
||
| 3 |
YearPlantOriginallyConstructed Year Originally Constructed |
|
|
|
|
|
|
| 4 |
YearLastUnitOfPlantInstalled Year Last Unit was Installed |
|
|
|
|
|
|
| 5 |
InstalledCapacityOfPlant Total Installed Cap (Max Gen Name Plate Ratings-MW) |
|
|
|
|
|
|
| 6 |
NetPeakDemandOnPlant Net Peak Demand on Plant - MW (60 minutes) |
|
|
|
|
|
|
| 7 |
PlantHoursConnectedToLoad Plant Hours Connected to Load |
|
|
|
|
|
|
| 8 |
NetContinuousPlantCapability Net Continuous Plant Capability (Megawatts) |
||||||
| 9 |
NetContinuousPlantCapabilityNotLimitedByCondenserWater When Not Limited by Condenser Water |
|
|
|
|
|
|
| 10 |
NetContinuousPlantCapabilityLimitedByCondenserWater When Limited by Condenser Water |
|
|
|
|
|
|
| 11 |
PlantAverageNumberOfEmployees Average Number of Employees |
|
|
|
|
|
|
| 12 |
NetGenerationExcludingPlantUse Net Generation, Exclusive of Plant Use - kWh |
|
|
|
|
|
|
| 13 |
CostOfLandAndLandRightsSteamProduction Cost of Plant: Land and Land Rights |
|
|
|
|
|
|
| 14 |
CostOfStructuresAndImprovementsSteamProduction Structures and Improvements |
|
|
|
|
|
|
| 15 |
CostOfEquipmentSteamProduction Equipment Costs |
|
|
|
|
|
|
| 16 |
AssetRetirementCostsSteamProduction Asset Retirement Costs |
|
|
||||
| 17 |
CostOfPlant Total cost (total 13 thru 20) |
|
|
|
|
|
|
| 18 |
CostPerKilowattOfInstalledCapacity Cost per KW of Installed Capacity (line 17/5) Including |
|
|
|
|
|
|
| 19 |
OperationSupervisionAndEngineeringExpense Production Expenses: Oper, Supv, & Engr |
|
|
|
|
|
|
| 20 |
FuelSteamPowerGeneration Fuel |
|
|
|
|
|
|
| 21 |
CoolantsAndWater Coolants and Water (Nuclear Plants Only) |
|
|||||
| 22 |
SteamExpensesSteamPowerGeneration Steam Expenses |
|
|
|
|
|
|
| 23 |
SteamFromOtherSources Steam From Other Sources |
|
|||||
| 24 |
SteamTransferredCredit Steam Transferred (Cr) |
|
|||||
| 25 |
ElectricExpensesSteamPowerGeneration Electric Expenses |
|
|
|
|
|
|
| 26 |
MiscellaneousSteamPowerExpenses Misc Steam (or Nuclear) Power Expenses |
|
|
|
|
|
|
| 27 |
RentsSteamPowerGeneration Rents |
|
|
|
|
|
|
| 28 |
Allowances Allowances |
|
|
|
|
|
|
| 29 |
MaintenanceSupervisionAndEngineeringSteamPowerGeneration Maintenance Supervision and Engineering |
|
|
|
|
|
|
| 30 |
MaintenanceOfStructuresSteamPowerGeneration Maintenance of Structures |
|
|
|
|
|
|
| 31 |
MaintenanceOfBoilerPlantSteamPowerGeneration Maintenance of Boiler (or reactor) Plant |
|
|
|
|
|
|
| 32 |
MaintenanceOfElectricPlantSteamPowerGeneration Maintenance of Electric Plant |
|
|
|
|
|
|
| 33 |
MaintenanceOfMiscellaneousSteamPlant Maintenance of Misc Steam (or Nuclear) Plant |
|
|
|
|
|
|
| 34 |
PowerProductionExpensesSteamPower Total Production Expenses |
|
|
|
|
|
|
| 35 |
ExpensesPerNetKilowattHour Expenses per Net kWh |
|
|
|
|
|
| 35 |
FuelKindAxis Plant Name |
Attala |
Baxter Wilson |
Baxter Wilson |
Choctaw |
Gerald Andrus |
Gerald Andrus |
Hinds |
Independence |
Independence |
| 36 |
FuelKind Fuel Kind |
|
|
|
|
|
|
|
|
|
| 37 |
FuelUnit Fuel Unit |
|
|
|
|
|
|
|
|
|
| 38 |
QuantityOfFuelBurned Quantity (Units) of Fuel Burned |
|
|
|
|
|
|
|
|
|
| 39 |
FuelBurnedAverageHeatContent Avg Heat Cont - Fuel Burned (btu/indicate if nuclear) |
|
|
|
|
|
|
|
|
|
| 40 |
AverageCostOfFuelPerUnitAsDelivered Avg Cost of Fuel/unit, as Delvd f.o.b. during year |
|||||||||
| 41 |
AverageCostOfFuelPerUnitBurned Average Cost of Fuel per Unit Burned |
|
|
|
|
|
|
|
||
| 42 |
AverageCostOfFuelBurnedPerMillionBritishThermalUnit Average Cost of Fuel Burned per Million BTU |
|
|
|
|
|
|
|
||
| 43 |
AverageCostOfFuelBurnedPerKilowattHourNetGeneration Average Cost of Fuel Burned per kWh Net Gen |
|||||||||
| 44 |
AverageBritishThermalUnitPerKilowattHourNetGeneration Average BTU per kWh Net Generation |
|
|
|
|
|
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: PlantName |
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
Hydroelectric Generating Plant Statistics |
|
| Line No. |
Item
(a)
|
FERC Licensed Project No.
Plant Name:
|
| 1 |
PlantKind Kind of Plant (Run-of-River or Storage) |
|
| 2 |
PlantConstructionType Plant Construction type (Conventional or Outdoor) |
|
| 3 |
YearPlantOriginallyConstructed Year Originally Constructed |
|
| 4 |
YearLastUnitOfPlantInstalled Year Last Unit was Installed |
|
| 5 |
InstalledCapacityOfPlant Total installed cap (Gen name plate Rating in MW) |
|
| 6 |
NetPeakDemandOnPlant Net Peak Demand on Plant-Megawatts (60 minutes) |
|
| 7 |
PlantHoursConnectedToLoad Plant Hours Connect to Load |
|
| 8 |
NetPlantCapabilityAbstract Net Plant Capability (in megawatts) |
|
| 9 |
NetPlantCapabilityUnderMostFavorableOperatingConditions (a) Under Most Favorable Oper Conditions |
|
| 10 |
NetPlantCapabilityUnderMostAdverseOperatingConditions (b) Under the Most Adverse Oper Conditions |
|
| 11 |
PlantAverageNumberOfEmployees Average Number of Employees |
|
| 12 |
NetGenerationExcludingPlantUse Net Generation, Exclusive of Plant Use - kWh |
|
| 13 |
CostOfPlantAbstract Cost of Plant |
|
| 14 |
CostOfLandAndLandRightsHydroelectricProduction Land and Land Rights |
|
| 15 |
CostOfStructuresAndImprovementsHydroelectricProduction Structures and Improvements |
|
| 16 |
CostOfReservoirsDamsAndWaterwaysHydroelectricProduction Reservoirs, Dams, and Waterways |
|
| 17 |
EquipmentCostsHydroelectricProduction Equipment Costs |
|
| 18 |
CostOfRoadsRailroadsAndBridgesHydroelectricProduction Roads, Railroads, and Bridges |
|
| 19 |
AssetRetirementCostsHydroelectricProduction Asset Retirement Costs |
|
| 20 |
CostOfPlant Total cost (total 13 thru 20) |
|
| 21 |
CostPerKilowattOfInstalledCapacity Cost per KW of Installed Capacity (line 20 / 5) |
|
| 22 |
ProductionExpensesAbstract Production Expenses |
|
| 23 |
OperationSupervisionAndEngineeringExpense Operation Supervision and Engineering |
|
| 24 |
WaterForPower Water for Power |
|
| 25 |
HydraulicExpenses Hydraulic Expenses |
|
| 26 |
ElectricExpensesHydraulicPowerGeneration Electric Expenses |
|
| 27 |
MiscellaneousHydraulicPowerGenerationExpenses Misc Hydraulic Power Generation Expenses |
|
| 28 |
RentsHydraulicPowerGeneration Rents |
|
| 29 |
MaintenanceSupervisionAndEngineeringHydraulicPowerGeneration Maintenance Supervision and Engineering |
|
| 30 |
MaintenanceOfStructuresHydraulicPowerGeneration Maintenance of Structures |
|
| 31 |
MaintenanceOfReservoirsDamsAndWaterways Maintenance of Reservoirs, Dams, and Waterways |
|
| 32 |
MaintenanceOfElectricPlantHydraulicPowerGeneration Maintenance of Electric Plant |
|
| 33 |
MaintenanceOfMiscellaneousHydraulicPlant Maintenance of Misc Hydraulic Plant |
|
| 34 |
PowerProductionExpensesHydraulicPower Total Production Expenses (total 23 thru 33) |
|
| 35 |
ExpensesPerNetKilowattHour Expenses per net kWh |
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
|
Pumped Storage Generating Plant Statistics |
|||||||
|
|||||||
| Line No. |
Item
(a)
|
FERC Licensed Project No.
Plant Name:
|
|||||
| 1 |
PlantConstructionType Type of Plant Construction (Conventional or Outdoor) |
||||||
| 2 |
YearPlantOriginallyConstructed Year Originally Constructed |
||||||
| 3 |
YearLastUnitOfPlantInstalled Year Last Unit was Installed |
||||||
| 4 |
InstalledCapacityOfPlant Total installed cap (Gen name plate Rating in MW) |
||||||
| 5 |
NetPeakDemandOnPlant Net Peak Demaind on Plant-Megawatts (60 minutes) |
||||||
| 6 |
PlantHoursConnectedToLoad Plant Hours Connect to Load While Generating |
||||||
| 7 |
NetContinuousPlantCapability Net Plant Capability (in megawatts) |
||||||
| 8 |
PlantAverageNumberOfEmployees Average Number of Employees |
||||||
| 9 |
NetGenerationExcludingPlantUse Generation, Exclusive of Plant Use - kWh |
||||||
| 10 |
EnergyUsedForPumping Energy Used for Pumping |
||||||
| 11 |
NetOutputForLoad Net Output for Load (line 9 - line 10) - Kwh |
|
|||||
| 12 |
CostOfPlantAbstract Cost of Plant |
||||||
| 13 |
CostOfLandAndLandRightsPumpedStoragePlant Land and Land Rights |
||||||
| 14 |
CostOfStructuresAndImprovementsPumpedStoragePlant Structures and Improvements |
||||||
| 15 |
CostOfReservoirsDamsAndWaterwaysPumpedStoragePlant Reservoirs, Dams, and Waterways |
||||||
| 16 |
CostOfWaterWheelsTurbinesAndGeneratorsPumpedStoragePlant Water Wheels, Turbines, and Generators |
||||||
| 17 |
CostOfAccessoryElectricEquipmentPumpedStoragePlant Accessory Electric Equipment |
||||||
| 18 |
CostOfMiscellaneousPowerPlantEquipmentPumpedStoragePlant Miscellaneous Powerplant Equipment |
||||||
| 19 |
CostOfRoadsRailroadsAndBridgesPumpedStoragePlant Roads, Railroads, and Bridges |
||||||
| 20 |
AssetRetirementCostsPumpedStoragePlant Asset Retirement Costs |
||||||
| 21 |
CostOfPlant Total cost (total 13 thru 20) |
||||||
| 22 |
CostPerKilowattOfInstalledCapacity Cost per KW of installed cap (line 21 / 4) |
||||||
| 23 |
ProductionExpensesAbstract Production Expenses |
||||||
| 24 |
OperationSupervisionAndEngineeringExpense Operation Supervision and Engineering |
||||||
| 25 |
WaterForPower Water for Power |
||||||
| 26 |
PumpedStorageExpenses Pumped Storage Expenses |
||||||
| 27 |
ElectricExpensesPumpedStoragePlant Electric Expenses |
||||||
| 28 |
MiscellaneousPumpedStoragePowerGenerationExpenses Misc Pumped Storage Power generation Expenses |
||||||
| 29 |
RentsPumpedStoragePlant Rents |
||||||
| 30 |
MaintenanceSupervisionAndEngineeringPumpedStoragePlant Maintenance Supervision and Engineering |
||||||
| 31 |
MaintenanceOfStructuresPumpedStoragePlant Maintenance of Structures |
||||||
| 32 |
MaintenanceOfReservoirsDamsAndWaterwaysPumpedStoragePlant Maintenance of Reservoirs, Dams, and Waterways |
||||||
| 33 |
MaintenanceOfElectricPlantPumpedStoragePlant Maintenance of Electric Plant |
||||||
| 34 |
MaintenanceOfMiscellaneousPumpedStoragePlant Maintenance of Misc Pumped Storage Plant |
||||||
| 35 |
PowerProductionExpenseBeforePumpingExpenses Production Exp Before Pumping Exp (24 thru 34) |
||||||
| 36 |
PumpingExpenses Pumping Expenses |
||||||
| 37 |
PowerProductionExpensesPumpedStoragePlant Total Production Exp (total 35 and 36) |
||||||
| 38 |
ExpensesPerNetKilowattHour Expenses per kWh (line 37 / 9) |
||||||
| 39 |
ExpensesPerNetKilowattHourGenerationAndPumping Expenses per KWh of Generation and Pumping (line 37/(line 9 + line 10)) |
|
|||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
GENERATING PLANT STATISTICS (Small Plants) |
|||||||||||||
|
|||||||||||||
| Production Expenses | |||||||||||||
| Line No. |
PlantName Name of Plant (a) |
YearPlantOriginallyConstructed Year Orig. Const. (b) |
InstalledCapacityOfPlant Installed Capacity Name Plate Rating (MW) (c) |
NetPeakDemandOnPlant Net Peak Demand MW (60 min) (d) |
NetGenerationExcludingPlantUse Net Generation Excluding Plant Use (e) |
CostOfPlant Cost of Plant (f) |
PlantCostPerMw Plant Cost (Incl Asset Retire. Costs) Per MW (g) |
OperatingExpensesExcludingFuel Operation Exc'l. Fuel (h) |
FuelProductionExpenses Fuel Production Expenses (i) |
MaintenanceProductionExpenses Maintenance Production Expenses (j) |
FuelKind Kind of Fuel (k) |
FuelCostPerMmbtus Fuel Costs (in cents (per Million Btu) (l) |
GenerationType Generation Type (m) |
| 1 | |||||||||||||
| 2 | |||||||||||||
| 3 | |||||||||||||
| 4 | |||||||||||||
| 5 | |||||||||||||
| 6 | |||||||||||||
| 7 | |||||||||||||
| 8 | |||||||||||||
| 9 | |||||||||||||
| 10 | |||||||||||||
| 11 | |||||||||||||
| 12 | |||||||||||||
| 13 | |||||||||||||
| 14 | |||||||||||||
| 15 | |||||||||||||
| 16 | |||||||||||||
| 17 | |||||||||||||
| 18 | |||||||||||||
| 19 | |||||||||||||
| 20 | |||||||||||||
| 21 | |||||||||||||
| 22 | |||||||||||||
| 23 | |||||||||||||
| 24 | |||||||||||||
| 25 | |||||||||||||
| 26 | |||||||||||||
| 27 | |||||||||||||
| 28 | |||||||||||||
| 29 | |||||||||||||
| 30 | |||||||||||||
| 31 | |||||||||||||
| 32 | |||||||||||||
| 33 | |||||||||||||
| 34 | |||||||||||||
| 35 | |||||||||||||
| 36 | |||||||||||||
| 37 | |||||||||||||
| 38 | |||||||||||||
| 39 | |||||||||||||
| 40 | |||||||||||||
| 41 | |||||||||||||
| 42 | |||||||||||||
| 43 | |||||||||||||
| 44 | |||||||||||||
| 45 | |||||||||||||
| 46 | |||||||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
ENERGY STORAGE OPERATIONS (Large Plants) |
|||||||||||||||||||
|
|||||||||||||||||||
| Line No. |
Name of the Energy Storage Project (a) |
Functional Classification (b) |
Location of the Project (c) |
MWHs (d) |
MWHs delivered to the grid to support Production (e) |
MWHs delivered to the grid to support Transmission (f) |
MWHs delivered to the grid to support Distribution (g) |
MWHs Lost During Conversion, Storage and Discharge of Energy Production (h) |
MWHs Lost During Conversion, Storage and Discharge of Energy Transmission (i) |
MWHs Lost During Conversion, Storage and Discharge of Energy Distribution (j) |
MWHs Sold (k) |
Revenues from Energy Storage Operations (l) |
Power Purchased for Storage Operations (555.1) (Dollars) (m) |
Fuel Costs from associated fuel accounts for Storage Operations Associated with Self- Generated Power (Dollars) (n) |
Other Costs Associated with Self-Generated Power (Dollars) (o) |
Account for Project Costs (p) |
Production (Dollars) (q) |
Transmission (Dollars) (r) |
Distribution (Dollars) (s) |
| 1 | |||||||||||||||||||
| 2 | |||||||||||||||||||
| 3 | |||||||||||||||||||
| 4 | |||||||||||||||||||
| 5 | |||||||||||||||||||
| 6 | |||||||||||||||||||
| 7 | |||||||||||||||||||
| 8 | |||||||||||||||||||
| 9 | |||||||||||||||||||
| 10 | |||||||||||||||||||
| 11 | |||||||||||||||||||
| 12 | |||||||||||||||||||
| 13 | |||||||||||||||||||
| 14 | |||||||||||||||||||
| 15 | |||||||||||||||||||
| 16 | |||||||||||||||||||
| 17 | |||||||||||||||||||
| 18 | |||||||||||||||||||
| 19 | |||||||||||||||||||
| 20 | |||||||||||||||||||
| 21 | |||||||||||||||||||
| 22 | |||||||||||||||||||
| 23 | |||||||||||||||||||
| 24 | |||||||||||||||||||
| 25 | |||||||||||||||||||
| 26 | |||||||||||||||||||
| 27 | |||||||||||||||||||
| 28 | |||||||||||||||||||
| 29 | |||||||||||||||||||
| 30 | |||||||||||||||||||
| 31 | |||||||||||||||||||
| 32 | |||||||||||||||||||
| 33 | |||||||||||||||||||
| 34 | |||||||||||||||||||
| 35 | TOTAL |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
ENERGY STORAGE OPERATIONS (Small Plants) |
|||||||||
|
|||||||||
| BALANCE AT BEGINNING OF YEAR | |||||||||
| Line No. |
Name of the Energy Storage Project (a) |
Functional Classification (b) |
Location of the Project (c) |
Project Cost (d) |
Operations (Excluding Fuel used in Storage Operations) (e) |
Maintenance (f) |
Cost of fuel used in storage operations (g) |
Account No. 555.1, Power Purchased for Storage Operations (h) |
Other Expenses (i) |
| 1 | |||||||||
| 2 | |||||||||
| 3 | |||||||||
| 4 | |||||||||
| 5 | |||||||||
| 6 | |||||||||
| 7 | |||||||||
| 8 | |||||||||
| 9 | |||||||||
| 10 | |||||||||
| 11 | |||||||||
| 12 | |||||||||
| 13 | |||||||||
| 14 | |||||||||
| 15 | |||||||||
| 16 | |||||||||
| 17 | |||||||||
| 18 | |||||||||
| 19 | |||||||||
| 20 | |||||||||
| 21 | |||||||||
| 22 | |||||||||
| 23 | |||||||||
| 24 | |||||||||
| 25 | |||||||||
| 26 | |||||||||
| 27 | |||||||||
| 28 | |||||||||
| 29 | |||||||||
| 30 | |||||||||
| 31 | |||||||||
| 32 | |||||||||
| 33 | |||||||||
| 34 | |||||||||
| 35 | |||||||||
| 36 | TOTAL |
|
|
|
|
|
|
||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
TRANSMISSION LINE STATISTICS |
||||||||||||||||
|
||||||||||||||||
| DESIGNATION | VOLTAGE (KV) - (Indicate where other than 60 cycle, 3 phase) | LENGTH (Pole miles) - (In the case of underground lines report circuit miles) | COST OF LINE (Include in column (j) Land, Land rights, and clearing right-of-way) | EXPENSES, EXCEPT DEPRECIATION AND TAXES | ||||||||||||
| Line No. |
TransmissionLineStartPoint From |
TransmissionLineEndPoint To |
OperatingVoltageOfTransmissionLine Operating |
DesignedVoltageOfTransmissionLine Designated |
SupportingStructureOfTransmissionLineType Type of Supporting Structure |
LengthForStandAloneTransmissionLines On Structure of Line Designated |
LengthForTransmissionLinesAggregatedWithOtherStructures On Structures of Another Line |
NumberOfTransmissionCircuits Number of Circuits |
SizeOfConductorAndMaterial Size of Conductor and Material |
CostOfLandAndLandRightsTransmissionLines Land |
ConstructionAndOtherCostsTransmissionLines Construction Costs |
OverallCostOfTransmissionLine Total Costs |
OperatingExpensesOfTransmissionLine Operation Expenses |
MaintenanceExpensesOfTransmissionLine Maintenance Expenses |
RentExpensesOfTransmissionLine Rents |
OverallExpensesOfTransmissionLine Total Expenses |
|
(a) |
(b) |
(c) |
(d) |
(e) |
(f) |
(g) |
(h) |
(i) |
(j) |
(k) |
(l) |
(m) |
(n) |
(o) |
(p) |
|
| 1 | ||||||||||||||||
| 2 | ||||||||||||||||
| 3 | ||||||||||||||||
| 4 | ||||||||||||||||
| 5 | ||||||||||||||||
| 6 | ||||||||||||||||
| 7 | ||||||||||||||||
| 8 | ||||||||||||||||
| 9 | ||||||||||||||||
| 10 | ||||||||||||||||
| 11 | ||||||||||||||||
| 12 | ||||||||||||||||
| 13 | ||||||||||||||||
| 14 | ||||||||||||||||
| 15 | ||||||||||||||||
| 16 | ||||||||||||||||
| 17 | ||||||||||||||||
| 18 | ||||||||||||||||
| 19 | ||||||||||||||||
| 20 | ||||||||||||||||
| 21 | ||||||||||||||||
| 22 | ||||||||||||||||
| 23 | ||||||||||||||||
| 24 | ||||||||||||||||
| 25 | ||||||||||||||||
| 26 | ||||||||||||||||
| 27 | ||||||||||||||||
| 28 | ||||||||||||||||
| 29 | ||||||||||||||||
| 30 | ||||||||||||||||
| 31 | ||||||||||||||||
| 32 | ||||||||||||||||
| 33 | ||||||||||||||||
| 34 | ||||||||||||||||
| 35 | ||||||||||||||||
| 36 | ||||||||||||||||
| 37 | ||||||||||||||||
| 38 | ||||||||||||||||
| 39 | ||||||||||||||||
| 40 | ||||||||||||||||
| 41 | ||||||||||||||||
| 42 | ||||||||||||||||
| 43 | ||||||||||||||||
| 44 | ||||||||||||||||
| 45 | ||||||||||||||||
| 46 | ||||||||||||||||
| 47 | ||||||||||||||||
| 48 | ||||||||||||||||
| 49 | ||||||||||||||||
| 50 | ||||||||||||||||
| 51 | ||||||||||||||||
| 52 | ||||||||||||||||
| 53 | ||||||||||||||||
| 54 | ||||||||||||||||
| 55 | ||||||||||||||||
| 56 | ||||||||||||||||
| 57 | ||||||||||||||||
| 36 | TOTAL |
|
|
|
|
|
|
|
|
|
|
|||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
TRANSMISSION LINES ADDED DURING YEAR |
||||||||||||||||||
|
||||||||||||||||||
| LINE DESIGNATION | SUPPORTING STRUCTURE | CIRCUITS PER STRUCTURE | CONDUCTORS | LINE COST | ||||||||||||||
| Line No. |
TransmissionLineStartPoint From |
TransmissionLineEndPoint To |
LengthOfTransmissionLineAdded Line Length in Miles |
SupportingStructureOfTransmissionLineType Type |
AverageNumberOfSupportingStructuresOfTransmissionLinePerMiles Average Number per Miles |
NumberOfTransmissionCircuitsPerStructurePresent Present |
NumberOfTransmissionCircuitsPerStructureUltimate Ultimate |
ConductorSize Size |
ConductorSpecification Specification |
ConductorConfigurationAndSpacing Configuration and Spacing |
OperatingVoltageOfTransmissionLine Voltage KV (Operating) |
CostOfLandAndLandRightsTransmissionLinesAdded Land and Land Rights |
CostOfPolesTowersAndFixturesTransmissionLinesAdded Poles, Towers and Fixtures |
CostOfConductorsAndDevicesTransmissionLinesAdded Conductors and Devices |
Asset Retire. Costs |
CostOfTransmissionLinesAdded Total |
SupportingStructureConstructionType Construction |
|
|
(a) |
(b) |
(c) |
(d) |
(e) |
(f) |
(g) |
(h) |
(i) |
(j) |
(k) |
(l) |
(m) |
(n) |
(o) |
(p) |
(q) |
||
| 1 | ||||||||||||||||||
| 2 | ||||||||||||||||||
| 3 | ||||||||||||||||||
| 4 | ||||||||||||||||||
| 5 | ||||||||||||||||||
| 6 | ||||||||||||||||||
| 7 | ||||||||||||||||||
| 8 | ||||||||||||||||||
| 9 | ||||||||||||||||||
| 10 | ||||||||||||||||||
| 11 | ||||||||||||||||||
| 12 | ||||||||||||||||||
| 13 | ||||||||||||||||||
| 14 | ||||||||||||||||||
| 15 | ||||||||||||||||||
| 16 | ||||||||||||||||||
| 17 | ||||||||||||||||||
| 18 | ||||||||||||||||||
| 19 | ||||||||||||||||||
| 20 | ||||||||||||||||||
| 21 | ||||||||||||||||||
| 22 | ||||||||||||||||||
| 23 | ||||||||||||||||||
| 24 | ||||||||||||||||||
| 25 | ||||||||||||||||||
| 26 | ||||||||||||||||||
| 27 | ||||||||||||||||||
| 28 | ||||||||||||||||||
| 29 | ||||||||||||||||||
| 30 | ||||||||||||||||||
| 31 | ||||||||||||||||||
| 32 | ||||||||||||||||||
| 33 | ||||||||||||||||||
| 34 | ||||||||||||||||||
| 35 | ||||||||||||||||||
| 36 | ||||||||||||||||||
| 37 | ||||||||||||||||||
| 38 | ||||||||||||||||||
| 39 | ||||||||||||||||||
| 40 | ||||||||||||||||||
| 41 | ||||||||||||||||||
| 42 | ||||||||||||||||||
| 43 | ||||||||||||||||||
| 44 |
TOTAL |
|
|
|
|
|||||||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
SUBSTATIONS |
||||||||||||
|
||||||||||||
| Character of Substation | VOLTAGE (In MVa) | Conversion Apparatus and Special Equipment | ||||||||||
| Line No. |
SubstationNameAndLocation Name and Location of Substation (a) |
SubstationCharacterDescription Transmission or Distribution (b) |
SubstationCharacterAttendedOrUnattended Attended or Unattended (b-1) |
PrimaryVoltageLevel Primary Voltage (In MVa) (c) |
SecondaryVoltageLevel Secondary Voltage (In MVa) (d) |
TertiaryVoltageLevel Tertiary Voltage (In MVa) (e) |
SubstationInServiceCapacity Capacity of Substation (In Service) (In MVa) (f) |
NumberOfTransformersInService Number of Transformers In Service (g) |
Number of Spare Transformers (h) |
ConversionApparatusAndSpecialEquipmentType Type of Equipment (i) |
NumberOfConversionApparatusAndSpecialEquipmentUnits Number of Units (j) |
CapacityOfConversionApparatusAndSpecialEquipment Total Capacity (In MVa) (k) |
| 1 | (a) |
(b) |
||||||||||
| 2 | ||||||||||||
| 3 | ||||||||||||
| 4 | ||||||||||||
| 5 | ||||||||||||
| 6 | ||||||||||||
| 7 | ||||||||||||
| 8 | ||||||||||||
| 9 | ||||||||||||
| 10 | ||||||||||||
| 11 | ||||||||||||
| 12 | ||||||||||||
| 13 | ||||||||||||
| 14 | ||||||||||||
| 15 | ||||||||||||
| 16 | ||||||||||||
| 17 | ||||||||||||
| 18 | ||||||||||||
| 19 | ||||||||||||
| 20 | ||||||||||||
| 21 | ||||||||||||
| 22 | ||||||||||||
| 23 | ||||||||||||
| 24 | ||||||||||||
| 25 | ||||||||||||
| 26 | ||||||||||||
| 27 | ||||||||||||
| 28 | ||||||||||||
| 29 | ||||||||||||
| 30 | ||||||||||||
| 31 | ||||||||||||
| 32 | ||||||||||||
| 33 | ||||||||||||
| 34 | ||||||||||||
| 35 | ||||||||||||
| 36 | ||||||||||||
| 37 | ||||||||||||
| 38 | ||||||||||||
| 39 | ||||||||||||
| 40 | ||||||||||||
| 41 | ||||||||||||
| 42 | ||||||||||||
| 43 | ||||||||||||
| 44 | ||||||||||||
| 45 | ||||||||||||
| 46 | ||||||||||||
| 47 | ||||||||||||
| 48 | ||||||||||||
| 49 | ||||||||||||
| 50 | ||||||||||||
| 51 | ||||||||||||
| 52 | ||||||||||||
| 53 | ||||||||||||
| 54 | ||||||||||||
| 55 | ||||||||||||
| 56 | ||||||||||||
| 57 | ||||||||||||
| 58 | ||||||||||||
| 59 | ||||||||||||
| 60 | ||||||||||||
| 61 | ||||||||||||
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| 64 | ||||||||||||
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| 72 | ||||||||||||
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| 77 | ||||||||||||
| 78 | ||||||||||||
| 79 | ||||||||||||
| 80 | ||||||||||||
| 81 | ||||||||||||
| 82 | ||||||||||||
| 83 | ||||||||||||
| 84 | ||||||||||||
| 85 | ||||||||||||
| 86 | ||||||||||||
| 87 | ||||||||||||
| 88 | ||||||||||||
| 89 | ||||||||||||
| 90 | ||||||||||||
| 91 | ||||||||||||
| 92 | ||||||||||||
| 93 | ||||||||||||
| 94 | ||||||||||||
| 95 | ||||||||||||
| 96 | ||||||||||||
| 97 | ||||||||||||
| 98 | ||||||||||||
| 99 | ||||||||||||
| 100 | ||||||||||||
| 101 | ||||||||||||
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| 112 | ||||||||||||
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| 114 | ||||||||||||
| 115 | ||||||||||||
| 116 | ||||||||||||
| 117 | ||||||||||||
| 118 | ||||||||||||
| 119 | ||||||||||||
| 120 | ||||||||||||
| 121 | ||||||||||||
| 122 | ||||||||||||
| 123 | ||||||||||||
| 124 | ||||||||||||
| 125 | ||||||||||||
| 126 | ||||||||||||
| 127 | ||||||||||||
| 128 | ||||||||||||
| 129 | ||||||||||||
| 130 | ||||||||||||
| 131 | ||||||||||||
| 132 | ||||||||||||
| 133 | ||||||||||||
| 134 | ||||||||||||
| 135 | ||||||||||||
| 136 | ||||||||||||
| 137 | ||||||||||||
| 138 | ||||||||||||
| 139 | ||||||||||||
| 140 | ||||||||||||
| 141 | ||||||||||||
| 142 | ||||||||||||
| 143 | ||||||||||||
| 144 | ||||||||||||
| 145 | ||||||||||||
| 146 | ||||||||||||
| 147 | ||||||||||||
| 148 | ||||||||||||
| 149 | ||||||||||||
| 150 | ||||||||||||
| 151 | ||||||||||||
| 152 | ||||||||||||
| 153 | ||||||||||||
| 154 | ||||||||||||
| 155 | ||||||||||||
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| 157 | ||||||||||||
| 158 | ||||||||||||
| 159 | ||||||||||||
| 160 | ||||||||||||
| 161 | ||||||||||||
| 162 | ||||||||||||
| 163 | ||||||||||||
| 164 | ||||||||||||
| 165 | ||||||||||||
| 166 | (c) |
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| 167 | ||||||||||||
| 168 | ||||||||||||
| 169 | ||||||||||||
| 170 | ||||||||||||
| 171 | ||||||||||||
| 172 | ||||||||||||
| 173 | ||||||||||||
| 174 | ||||||||||||
| 175 | ||||||||||||
| 176 | ||||||||||||
| 177 | ||||||||||||
| 178 | ||||||||||||
| 179 | ||||||||||||
| 180 | ||||||||||||
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| 182 | ||||||||||||
| 183 | ||||||||||||
| 184 | ||||||||||||
| 185 | ||||||||||||
| 186 | ||||||||||||
| 187 | ||||||||||||
| 188 | ||||||||||||
| 189 | ||||||||||||
| 190 | ||||||||||||
| 191 | ||||||||||||
| 192 | ||||||||||||
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| 194 | ||||||||||||
| 195 | ||||||||||||
| 196 | ||||||||||||
| 197 | ||||||||||||
| 198 | ||||||||||||
| 199 | ||||||||||||
| 200 | ||||||||||||
| 201 | ||||||||||||
| 202 | ||||||||||||
| 203 | ||||||||||||
| 204 | ||||||||||||
| 205 | TotalDistributionSubstationMember |
|||||||||||
| 206 | TotalGenerationSubstationMember |
|||||||||||
| 207 | TotalTransmissionSubstationMember |
|||||||||||
| 208 | Total |
|||||||||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: PrimaryVoltageLevel |
| (b) Concept: SecondaryVoltageLevel |
| (c) Concept: TertiaryVoltageLevel |
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
TRANSACTIONS WITH ASSOCIATED (AFFILIATED) COMPANIES |
||||
|
||||
| Line No. |
Description of the Good or Service (a) |
Name of Associated/Affiliated Company (b) |
Account(s) Charged or Credited (c) |
Amount Charged or Credited (d) |
| 1 |
Non-power Goods or Services Provided by Affiliated |
|||
| 2 | (a) |
|||
| 3 | (b) |
|||
| 19 | ||||
| 20 |
Non-power Goods or Services Provided for Affiliated |
|||
| 21 | ||||
| 22 | ||||
| 23 | ||||
| 24 | ||||
| 25 | ||||
| 26 | ||||
| 27 | ||||
| 28 | ||||
| 29 | ||||
| 30 | ||||
| 31 | ||||
| 32 | ||||
| 33 | ||||
| 34 | ||||
| 35 | ||||
| 36 | ||||
| 37 | ||||
| 38 | ||||
| 39 | ||||
| 40 | ||||
| 41 | ||||
| 42 | ||||
|
Name of Respondent: |
This report is: (1) ☑ An Original (2) ☐ A Resubmission |
Date of Report: |
Year/Period of Report End of: |
| FOOTNOTE DATA |
| (a) Concept: DescriptionOfNonPowerGoodOrService | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Non-power goods or services received from or provided to associated (affiliated) companies are reported in the schedule below by type of category, where the amount charged or credited from or to each affiliate is equal to or greater than the $250,000 threshold.
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Listed below are the allocation factors used to allocate costs to the affiliate.
Note: Where no allocation factor is provided for the non-power goods or services listed on Schedule 429, the costs associated with those goods and services were directly charged and not allocated.
Cost Allocator Descriptions
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